0001002910 aee:AmerenIllinoisCompanyMember aee:MethaneGasMember 2019-09-30

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q



ý☒	Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 ~~for the Quarterly Period Ended March 31, 2019~~

for the Quarterly Period Ended September 30, 2019



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



~~UNION ELECTRIC CO~~	~~AMEREN CORP~~	~~AMEREN ILLINOIS CO~~



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

(Missouri Corporation)

1901 Chouteau Avenue

St. Louis, Missouri63103

(314)621-3222

~~43-1723446~~
	~~(Missouri Corporation)~~
	~~1901 Chouteau Avenue~~
	~~St. Louis, Missouri 63103~~
	~~(314) 621-3222~~

1-2967	Union Electric Company	43-0559760

(Missouri Corporation)

1901 Chouteau Avenue

St. Louis, Missouri63103

(314)621-3222

~~43-0559760~~
	~~(Missouri Corporation)~~
	~~1901 Chouteau Avenue~~
	~~St. Louis, Missouri 63103~~
	~~(314) 621-3222~~

1-3672	Ameren Illinois Company	37-0211380
	~~(Illinois Corporation)~~
	~~10 Executive Drive~~
	~~Collinsville, Illinois 62234~~
	~~(618) 343-8150~~

(Illinois Corporation)

10 Executive Drive

Collinsville, Illinois62234

(618)343-8150

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 under the ticker symbol AEE:~~



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

Indicate by check mark whether the registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.



Ameren Corporation	Yes	ý☒	No	¨☐
Union Electric Company	Yes	ý☒	No	¨☐
Ameren Illinois Company	Yes	ý☒	No	¨☐

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



Ameren Corporation	Yes	ý☒	No	¨☐
Union Electric Company	Yes	ý☒	No	¨☐
Ameren Illinois Company	Yes	ý☒	No	¨☐

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



Ameren Corporation	Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐
		~~Large Accelerated~~ ~~Filer~~	Smaller reporting company	~~Accelerated~~ ~~Filer~~ ☐	Emerging growth company	~~Non-Accelerated~~ ~~Filer~~	~~Smaller Reporting~~ ~~Company~~	~~Emerging Growth~~ ~~Company~~
~~Ameren Corporation~~		ý		¨		¨	¨	¨☐
Union Electric Company	Large accelerated filer	¨☐	Accelerated filer	☐	Non-accelerated filer	☒
		¨	Smaller reporting company	ý☐	Emerging growth company	¨	¨☐
Ameren Illinois Company	Large accelerated filer	¨☐	Accelerated filer	☐	Non-accelerated filer	☒
		¨	Smaller reporting company	ý☐	Emerging growth company	¨	¨☐

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



Ameren Corporation	¨☐
Union Electric Company	¨☐
Ameren Illinois Company	¨☐

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



Ameren Corporation	Yes	¨☐	No	ý☒
Union Electric Company	Yes	¨☐	No	ý☒
Ameren Illinois Company	Yes	¨☐	No	ý☒

The number of shares outstanding of each registrant’s classes of common stock as of ~~April 30,~~October 31, 2019, was as follows:



Ameren Corporation	Common stock, $0.01 par value per share – ~~245,597,156~~	246,029,792
Union Electric Company	Common stock, $5 par value per share, held by Ameren Corporation –	102,123,834
Ameren Illinois Company	Common stock, no par value, held by Ameren Corporation –	25,452,373

______________________________________________________________________________________________________

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

TABLE OF CONTENTS



		Page
Glossary of Terms and Abbreviations		1

Forward-looking Statements		1

PART I. Financial Information

Item 1.	Financial Statements (Unaudited)	3
	Ameren Corporation	3
	Consolidated Statement of Income and Comprehensive Income	3
	Consolidated Balance Sheet	4
	Consolidated Statement of Cash Flows	5
	Consolidated Statement of Shareholders’ Equity	6
	Union Electric Company (d/b/a Ameren Missouri)	7
	Statement of Income	7
	Balance Sheet	8
	Statement of Cash Flows	9
	Statement of Shareholders’ Equity	10
	Ameren Illinois Company (d/b/a Ameren Illinois)	11
	Statement of Income	11
	Balance Sheet	12
	Statement of Cash Flows	13
	Statement of Shareholders’ Equity	14
	Note 1. Summary of Significant Accounting Policies	15
	Note 2. Rate and Regulatory Matters	16
	Note 3. Short-term Debt and Liquidity	18
	~~Note 4. Long-term Debt and Equity Financings~~	19
	Note ~~5. Other Income, Net~~	19
	~~Note 6. Derivative Financial Instruments~~4. Long-term Debt and Equity Financings	20
	Note ~~7. Fair Value Measurements~~5. Other Income, Net	21
	Note 6. Derivative Financial Instruments	22
	Note ~~8. Related-party Transactions~~7. Fair Value Measurements	2523
	Note ~~9. Commitments and Contingencies~~8. Related-party Transactions	2627
	Note ~~10. Callaway Energy Center~~9. Commitments and Contingencies	2928
	Note ~~11. Retirement Benefits~~10. Callaway Energy Center	31
	Note ~~12. Income Taxes~~11. Retirement Benefits	3133
	Note ~~13. Supplemental Information~~12. Income Taxes	3433
	Note 13. Supplemental Information	37
	Note 14. Segment Information	3437
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3742
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	5666
Item 4.	Controls and Procedures	5666

PART II. Other Information

Item 1.	Legal Proceedings	5766
Item 1A.	Risk Factors	5767
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	5767
Item 6.	Exhibits	5868

Signatures		5969

GLOSSARY OF TERMS AND ABBREVIATIONS

We use the words “our,” “we” or “us” with respect to certain information that relates to Ameren, Ameren Missouri, and Ameren Illinois, collectively. When appropriate, subsidiaries of Ameren Corporation are named specifically as their various business activities are discussed. Refer to the Form 10-K for a complete listing of glossary terms and abbreviations. Only new or significantly changed terms and abbreviations are included below.

Form 10-K – The combined Annual Report on Form 10-K for the year ended December 31, 2018, filed by the Ameren Companies with the SEC.

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 in the Form 10-K and elsewhere in this report and in our other filings with the SEC, could cause actual results to differ materially from management expectations suggested in such forward-looking statements:

regulatory, judicial, or legislative actions, and any changes in regulatory policies and ratemaking determinations, such as those that may result from the complaint case filed in February 2015 with the FERC, a new methodology to determine the allowed base return on common equity under the MISO tariff proposed by the FERC in November 2018, the Notices of Inquiry issued by the FERC in March 2019, Ameren Missouri’s ~~natural gas~~electric regulatory rate review filed with the MoPSC in ~~December 2018, an~~July 2019, a request for appeal filed with the Missouri Supreme Court by the MoOPC in ~~January~~November 2019 inrelated to Ameren Missouri’s RESRAM, ~~case,~~Ameren Missouri’s request for deferral accounting treatment of maintenance expenses related to scheduled Callaway refueling and maintenance outages filed with the MoPSC in October 2019, Ameren Illinois’ April 2019 annual electric distribution formula rate update filing, Ameren Illinois’ May 2019 annual electric energy-efficiency formula rate update, and future regulatory, judicial, or legislative actions that change regulatory recovery mechanisms;

the effect of Ameren Illinois’ participation in performance-based formula ratemaking frameworks under the IEIMA and the FEJA, including the direct relationship between Ameren Illinois' return on common equity and the 30-year United States Treasury bond yields, and the related financial commitments;

the effect of Missouri Senate Bill 564 on Ameren Missouri, including ~~as a result of~~customer rate caps pursuant to Ameren Missouri’s election to use ~~PISA and the resulting customer rate caps;~~PISA;

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, 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 return on equity;

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 returns on equity;

the cost and availability of fuel, such as ultra-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 Callaway energy center, 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, including their impact 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, including as a result of the implementation of the TCJA, 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;

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 ~~breakdowns or~~ failures of equipment in the operation of natural gas transmission and distribution systems and storage facilities, such as leaks, explosions, and mechanical problems, and compliance with natural gas safety regulations;

the effects of ~~breakdowns or~~ failures of electric generation, transmission, or distribution equipment or facilities, 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;

•

the impact of current environmental laws and new, more stringent, or changing requirements, including those related to the effect of NSR and Clean Air Act litigation, CO₂ and the ~~proposed repeal and replacement of the Clean Power Plan and potential~~ adoption and 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 requirements in Missouri and Illinois and with the zero emission standard in Illinois;

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 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 MISO or other RTOs ~~including the costs of such interconnections;~~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;

the impact of negative opinions of us or our utility services that our customers, 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, or negative media coverage;

the impact of adopting new accounting guidance;

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

legal and administrative proceedings; and

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

New factors emerge from time to time, and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement. Given these uncertainties, undue reliance should not be placed on these forward-looking statements. Except to the extent required by the federal securities laws, we undertake no obligation to update or revise publicly any forward-looking statements to reflect new information or future events.

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.

AMEREN CORPORATION

CONSOLIDATED STATEMENT OF INCOME AND COMPREHENSIVE INCOME

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


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018
Operating Revenues:
Electric	$	1,182	$	1,223	$	1,528	$	1,590	$	3,928	$	4,209
Natural gas	374		362		131		134		666		663
Total operating revenues	1,556		1,585		1,659		1,724		4,594		4,872
Operating Expenses:
Fuel	160		188		147		216		409		590
Purchased power	156		163		148		148		440		453
Natural gas purchased for resale	161		171		31		30		236		252
Other operations and maintenance	417		431		434		429		1,301		1,299
Depreciation and amortization	248		234		248		241		745		713
Taxes other than income taxes	126		125		131		127		375		374
Total operating expenses	1,268		1,312		1,139		1,191		3,506		3,681
Operating Income	288		273		520		533		1,088		1,191
Other Income, Net	29		23		34		32		99		84
Interest Charges	97		101		96		101		290		302
Income Before Income Taxes	220		195		458		464		897		973
Income Taxes	27		42		92		105		158		221
Net Income	193		153		366		359		739		752
Less: Net Income Attributable to Noncontrolling Interests	2		2		2		2		5		5
Net Income Attributable to Ameren Common Shareholders	$	191	$	151	$	364	$	357	$	734	$	747


Net Income	$	193	$	153	$	366	$	359	$	739	$	752
Other Comprehensive Income, Net of Taxes
Pension and other postretirement benefit plan activity, net of income taxes of $-, and $-, respectively	1		1
Pension and other postretirement benefit plan activity, net of income taxes of $-, $-, $-, and $-, respectively					—		2		1		1
Comprehensive Income	194		154		366		361		740		753
Less: Comprehensive Income Attributable to Noncontrolling Interests	2		2		2		2		5		5
Comprehensive Income Attributable to Ameren Common Shareholders	$	192	$	152	$	364	$	359	$	735	$	748


Earnings per Common Share – Basic and Diluted	$	0.78	$	0.62
Earnings per Common Share – Basic					$	1.48	$	1.46	$	2.99	$	3.06

Earnings per Common Share – Diluted					$	1.47	$	1.45	$	2.97	$	3.04

Weighted-average Common Shares Outstanding – Basic	244.9		242.9		245.9		244.1		245.5		243.6
Weighted-average Common Shares Outstanding – Diluted	246.4		244.4		247.5		246.3		247.0		245.5

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

AMEREN CORPORATION

CONSOLIDATED BALANCE SHEET

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

March 31, 2019 December 31, 2018
ASSETS
Current Assets:
Cash and cash equivalents $ 8
$ 16
Accounts receivable – trade (less allowance for doubtful accounts of $19 and $18, respectively) 517
463
Unbilled revenue 238
295
Miscellaneous accounts receivable 74
79
Inventories 402
483
Current regulatory assets 113
134
Other current assets 70
63
Total current assets 1,422
1,533
Property, Plant, and Equipment, Net 23,044
22,810
Investments and Other Assets:
Nuclear decommissioning trust fund 754
684
Goodwill 411
411
Regulatory assets 1,134
1,127
Other assets 744
650
Total investments and other assets 3,043
2,872
TOTAL ASSETS $ 27,509
$ 27,215
LIABILITIES AND EQUITY
Current Liabilities:
Current maturities of long-term debt $ 336
$ 580
Short-term debt 799
597
Accounts and wages payable 522
817
Taxes accrued 81
53
Interest accrued 81
93
Customer deposits 111
116
Current regulatory liabilities 161
149
Other current liabilities 301
282
Total current liabilities 2,392
2,687
Long-term Debt, Net 8,221
7,859
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes, net 2,666
2,623
Accumulated deferred investment tax credits 42
43
Regulatory liabilities 4,731
4,637
Asset retirement obligations 630
627
Pension and other postretirement benefits 558
558
Other deferred credits and liabilities 422
408
Total deferred credits and other liabilities 9,049
8,896
Commitments and Contingencies (Notes 2, 9, and 10)

Ameren Corporation Shareholders’ Equity:
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 245.6 and 244.5, respectively 2
2
Other paid-in capital, principally premium on common stock 5,625
5,627
Retained earnings 2,099
2,024
Accumulated other comprehensive loss (21 ) (22 )
Total Ameren Corporation shareholders’ equity 7,705
7,631
Noncontrolling Interests 142
142
Total equity 7,847
7,773
TOTAL LIABILITIES AND EQUITY $ 27,509
$ 27,215

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

AMEREN CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited) (In millions)
Three Months Ended March 31,
2019 2018
Cash Flows From Operating Activities:
Net income $ 193
$ 153
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization 245
230
Amortization of nuclear fuel 23
24
Amortization of debt issuance costs and premium/discounts 5
5
Deferred income taxes and investment tax credits, net 32
26
Allowance for equity funds used during construction (6 ) (5 )
Stock-based compensation costs 6
6
Other (8 ) 2
Changes in assets and liabilities:
Receivables 4
(26 )
Inventories 81
68
Accounts and wages payable (213 ) (249 )
Taxes accrued 28
49
Regulatory assets and liabilities 26
20
Assets, other (14 ) 1
Liabilities, other (11 ) (57 )
Pension and other postretirement benefits (4 ) 11
Net cash provided by operating activities 387
258
Cash Flows From Investing Activities:
Capital expenditures (544 ) (579 )
Nuclear fuel expenditures (21 ) (12 )
Purchases of securities – nuclear decommissioning trust fund (39 ) (38 )
Sales and maturities of securities – nuclear decommissioning trust fund 36
34
Other 1
(2 )
Net cash used in investing activities (567 ) (597 )
Cash Flows From Financing Activities:
Dividends on common stock (116 ) (111 )
Dividends paid to noncontrolling interest holders (2 ) (2 )
Short-term debt, net 202
475
Maturities of long-term debt (329 ) —
Issuances of long-term debt 450
—
Issuances of common stock 19
17
Employee payroll taxes related to stock-based compensation (29 ) (19 )
Debt issuance costs (4 ) —
Net cash provided by financing activities 191
360
Net change in cash, cash equivalents, and restricted cash 11
21
Cash, cash equivalents, and restricted cash at beginning of year 107
68
Cash, cash equivalents, and restricted cash at end of period $ 118
$ 89

Noncash financing activity – Issuance of common stock for stock-based compensation $ 54
$ 35

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

AMEREN CORPORATION
CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY
(Unaudited) (In millions, except per share amounts)
Three Months Ended March 31,
2019 2018
Common Stock $ 2
$ 2

Other Paid-in Capital:
Beginning of year 5,627
5,540
Shares issued under the DRPlus and 401(k) plan 19
17
Stock-based compensation activity (21 ) (11 )
Other paid-in capital, end of period 5,625
5,546

Retained Earnings:
Beginning of year 2,024
1,660
Net income attributable to Ameren common shareholders 191
151
Dividends (116 ) (111 )
Other —
(1 )
Retained earnings, end of period 2,099
1,699

Accumulated Other Comprehensive Income (Loss):
Deferred retirement benefit costs, beginning of year (22 ) (18 )
Change in deferred retirement benefit costs 1
1
Deferred retirement benefit costs, end of period (21 ) (17 )
Total accumulated other comprehensive loss, end of period (21 ) (17 )
Total Ameren Corporation Shareholders’ Equity $ 7,705
$ 7,230

Noncontrolling Interests:
Beginning of year 142
142
Net income attributable to noncontrolling interest holders 2
2
Dividends paid to noncontrolling interest holders (2 ) (2 )
Noncontrolling interests, end of period 142
142
Total Equity $ 7,847
$ 7,372

Common stock shares outstanding at beginning of year 244.5
242.6
Shares issued under the DRPlus and 401(k) plan 0.3
0.3
Shares issued for stock-based compensation 0.8
0.7
Common stock shares outstanding at end of period 245.6
243.6

Dividends per common share $ 0.4750
$ 0.4575



	September 30, 2019			December 31, 2018
ASSETS
Current Assets:
Cash and cash equivalents	$	20		$	16
Accounts receivable – trade (less allowance for doubtful accounts of $19 and $18, respectively)	478			463
Unbilled revenue	273			295
Miscellaneous accounts receivable	56			79
Inventories	488			483
Current regulatory assets	74			134
Other current assets	106			63
Total current assets	1,495			1,533
Property, Plant, and Equipment, Net	23,894			22,810
Investments and Other Assets:
Nuclear decommissioning trust fund	798			684
Goodwill	411			411
Regulatory assets	1,168			1,127
Other assets	780			650
Total investments and other assets	3,157			2,872
TOTAL ASSETS	$	28,546		$	27,215
LIABILITIES AND EQUITY
Current Liabilities:
Current maturities of long-term debt	$	336		$	580
Short-term debt	544			597
Accounts and wages payable	598			817
Taxes accrued	164			53
Current regulatory liabilities	121			149
Other current liabilities	522			491
Total current liabilities	2,285			2,687
Long-term Debt, Net	8,651			7,859
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and investment tax credits, net	2,902			2,666
Regulatory liabilities	4,845			4,637
Asset retirement obligations	671			627
Pension and other postretirement benefits	522			558
Other deferred credits and liabilities	466			408
Total deferred credits and other liabilities	9,406			8,896
Commitments and Contingencies (Notes 2, 9, and 10)
Ameren Corporation Shareholders’ Equity:
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 246.0 and 244.5, respectively	2			2
Other paid-in capital, principally premium on common stock	5,673			5,627
Retained earnings	2,408			2,024
Accumulated other comprehensive loss	(21		)	(22		)
Total Ameren Corporation shareholders’ equity	8,062			7,631
Noncontrolling Interests	142			142
Total equity	8,204			7,773
TOTAL LIABILITIES AND EQUITY	$	28,546		$	27,215

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



AMEREN CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited) (In millions)
	Nine Months Ended September 30,
	2019			2018
Cash Flows From Operating Activities:
Net income	$	739		$	752
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	745			699
Amortization of nuclear fuel	56			71
Amortization of debt issuance costs and premium/discounts	14			16
Deferred income taxes and investment tax credits, net	144			212
Allowance for equity funds used during construction	(20		)	(25		)
Stock-based compensation costs	15			15
Other	(11		)	21
Changes in assets and liabilities:
Receivables	10			(129		)
Inventories	(4		)	(4		)
Accounts and wages payable	(205		)	(198		)
Taxes accrued	118			92
Regulatory assets and liabilities	147			213
Assets, other	(56		)	(2		)
Liabilities, other	11			(45		)
Pension and other postretirement benefits	(35		)	(2		)
Net cash provided by operating activities	1,668			1,686
Cash Flows From Investing Activities:
Capital expenditures	(1,761		)	(1,689		)
Nuclear fuel expenditures	(26		)	(30		)
Purchases of securities – nuclear decommissioning trust fund	(192		)	(172		)
Sales and maturities of securities – nuclear decommissioning trust fund	184			159
Purchase of bonds	(207		)	—
Proceeds from sale of remarketed bonds	207			—
Other	(3		)	13
Net cash used in investing activities	(1,798		)	(1,719		)
Cash Flows From Financing Activities:
Dividends on common stock	(350		)	(334		)
Dividends paid to noncontrolling interest holders	(5		)	(5		)
Short-term debt, net	(53		)	36
Maturities of long-term debt	(329		)	(522		)
Issuances of long-term debt	900			853
Issuances of common stock	54			56
Employee payroll taxes related to stock-based compensation	(29		)	(19		)
Debt issuance costs	(10		)	(9		)
Other	—			1
Net cash provided by financing activities	178			57
Net change in cash, cash equivalents, and restricted cash	48			24
Cash, cash equivalents, and restricted cash at beginning of year	107			68
Cash, cash equivalents, and restricted cash at end of period	$	155		$	92

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

AMEREN CORPORATION CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions, except per share amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
Common Stock	$	2		$	2		$	2		$	2

Other Paid-in Capital:
Beginning of period	5,649			5,576			5,627			5,540
Shares issued under the DRPlus and 401(k) plan	17			16			54			56
Stock-based compensation activity	7			6			(8		)	2
Other paid-in capital, end of period	5,673			5,598			5,673			5,598

Retained Earnings:
Beginning of period	2,161			1,827			2,024			1,660
Net income attributable to Ameren common shareholders	364			357			734			747
Dividends	(117		)	(111		)	(350		)	(334		)
Retained earnings, end of period	2,408			2,073			2,408			2,073

Accumulated Other Comprehensive Income (Loss):
Deferred retirement benefit costs, beginning of period	(21		)	(19		)	(22		)	(18		)
Change in deferred retirement benefit costs	—			2			1			1
Deferred retirement benefit costs, end of period	(21		)	(17		)	(21		)	(17		)
Total accumulated other comprehensive loss, end of period	(21		)	(17		)	(21		)	(17		)
Total Ameren Corporation Shareholders’ Equity	$	8,062		$	7,656		$	8,062		$	7,656

Noncontrolling Interests:
Beginning of period	142			142			142			142
Net income attributable to noncontrolling interest holders	2			2			5			5
Dividends paid to noncontrolling interest holders	(2		)	(2		)	(5		)	(5		)
Noncontrolling interests, end of period	142			142			142			142
Total Equity	$	8,204		$	7,798		$	8,204		$	7,798


Common stock shares outstanding at beginning of period	245.8			244.0			244.5			242.6
Shares issued under the DRPlus and 401(k) plan	0.2			0.2			0.7			0.9
Shares issued for stock-based compensation	—			—			0.8			0.7
Common stock shares outstanding at end of period	246.0			244.2			246.0			244.2

Dividends per common share	$	0.4750		$	0.4575		$	1.4250		$	1.3725

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

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

STATEMENT OF INCOME

(Unaudited) (In millions)


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018
Operating Revenues:
Electric	$	704	$	741	$	1,040	$	1,111	$	2,517	$	2,782
Natural gas	54		51		19		18		98		94
Total operating revenues	758		792		1,059		1,129		2,615		2,876
Operating Expenses:
Fuel	160		188		147		216		409		590
Purchased power	51		42		49		49		160		131
Natural gas purchased for resale	27		24		6		5		41		37
Other operations and maintenance	224		232		242		234		720		707
Depreciation and amortization	140		136		138		137		417		411
Taxes other than income taxes	77		80		96		94		256		258
Total operating expenses	679		702		678		735		2,003		2,134
Operating Income	79		90		381		394		612		742
Other Income, Net	12		13		15		16		43		45
Interest Charges	47		51		44		50		136		152
Income Before Income Taxes	44		52		352		360		519		635
Income Taxes	4		13		51		65		70		132
Net Income	40		39		301		295		449		503
Preferred Stock Dividends	1		1		1		1		3		3
Net Income Available to Common Shareholder	$	39	$	38	$	300	$	294	$	446	$	500

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

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

BALANCE SHEET

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


	March 31, 2019		December 31, 2018		September 30, 2019		December 31, 2018
ASSETS
Current Assets:
Cash and cash equivalents	$	—	$	—	$	—	$	—
Accounts receivable – trade (less allowance for doubtful accounts of $7 and $7, respectively)	189		223
Accounts receivable – trade (less allowance for doubtful accounts of $8 and $7, respectively)					243		223
Accounts receivable – affiliates	20		14		20		14
Unbilled revenue	128		155		156		155
Miscellaneous accounts receivable	40		42		41		42
Inventories	329		358		356		358
Current regulatory assets	13		14
Other current assets	32		26		66		40
Total current assets	751		832		882		832
Property, Plant, and Equipment, Net	12,159		12,103		12,452		12,103
Investments and Other Assets:
Nuclear decommissioning trust fund	754		684		798		684
Regulatory assets	351		366		358		366
Other assets	356		306		370		306
Total investments and other assets	1,461		1,356		1,526		1,356
TOTAL ASSETS	$	14,371	$	14,291	$	14,860	$	14,291
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:
Current maturities of long-term debt	$	336	$	580	$	336	$	580
Short-term debt	55		55		144		55
Accounts and wages payable	224		428		261		428
Accounts payable – affiliates	69		69		126		69
Taxes accrued	62		27		148		27
Interest accrued	47		52
Current regulatory liabilities	64		68
Other current liabilities	128		123		240		243
Total current liabilities	985		1,402		1,255		1,402
Long-term Debt, Net	3,780		3,418		3,779		3,418
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes, net	1,536		1,534
Accumulated deferred investment tax credits	41		42
Accumulated deferred income taxes and investment tax credits, net					1,619		1,576
Regulatory liabilities	2,868		2,799		2,860		2,799
Asset retirement obligations	626		623		667		623
Pension and other postretirement benefits	227		228		211		228
Other deferred credits and liabilities	40		16		44		16
Total deferred credits and other liabilities	5,338		5,242		5,401		5,242
Commitments and Contingencies (Notes 2, 8, 9, and 10)
Shareholders’ Equity:
Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding	511		511		511		511
Other paid-in capital, principally premium on common stock	1,903		1,903		1,903		1,903
Preferred stock	80		80		80		80
Retained earnings	1,774		1,735		1,931		1,735
Total shareholders’ equity	4,268		4,229		4,425		4,229
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	14,371	$	14,291	$	14,860	$	14,291

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

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

STATEMENT OF CASH FLOWS

(Unaudited) (In millions)


	Three Months Ended March 31,						Nine Months Ended September 30,
	2019			2018			2019			2018
Cash Flows From Operating Activities:
Net income	$	40		$	39		$	449		$	503
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	138			132			419			398
Amortization of nuclear fuel	23			24			56			71
Amortization of debt issuance costs and premium/discounts	2			2			4			4
Deferred income taxes and investment tax credits, net	(1		)	(1		)	(9		)	4
Allowance for equity funds used during construction	(4		)	(4		)	(14		)	(19		)
Other	2			4			10			14
Changes in assets and liabilities:
Receivables	56			4			(32		)	(156		)
Inventories	29			5			3			3
Accounts and wages payable	(167		)	(192		)	(153		)	(168		)
Taxes accrued	44			36			148			148
Regulatory assets and liabilities	11			38			5			149
Assets, other	(16		)	(5		)	(37		)	—
Liabilities, other	(4		)	(10		)	(4		)	7
Pension and other postretirement benefits	(1		)	4			(5		)	3
Net cash provided by operating activities	152			76			840			961
Cash Flows From Investing Activities:
Capital expenditures	(240		)	(249		)	(751		)	(664		)
Nuclear fuel expenditures	(21		)	(12		)	(26		)	(30		)
Purchases of securities – nuclear decommissioning trust fund	(39		)	(38		)	(192		)	(172		)
Sales and maturities of securities – nuclear decommissioning trust fund	36			34			184			159
Purchase of bonds							(207		)	—
Proceeds from sale of remarketed bonds							207			—
Money pool advances, net							—			(28		)
Net cash used in investing activities	(264		)	(265		)	(785		)	(735		)
Cash Flows From Financing Activities:
Dividends on common stock	—			(50		)	(250		)	(225		)
Dividends on preferred stock	(1		)	(1		)	(3		)	(3		)
Short-term debt, net	—			243			89			(39		)
Maturities of long-term debt	(329		)	—			(329		)	(378		)
Issuances of long-term debt	450			—			450			423
Debt issuance costs	(4		)	—			(6		)	(4		)
Net cash provided by financing activities	116			192
Net cash used in financing activities							(49		)	(226		)
Net change in cash, cash equivalents, and restricted cash	4			3			6			—
Cash, cash equivalents, and restricted cash at beginning of year	8			7			8			7
Cash, cash equivalents, and restricted cash at end of period	$	12		$	10		$	14		$	7

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

UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)	UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)						UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)

	Three Months Ended March 31,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018
Common Stock	$	511		$	511		$	511		$	511		$	511		$	511

Other Paid-in Capital	1,903			1,858			1,903			1,858			1,903			1,858

Preferred Stock	80			80			80			80			80			80

Retained Earnings:
Beginning of year	1,735			1,632
Beginning of period							1,781			1,788			1,735			1,632
Net income	40			39			301			295			449			503
Common stock dividends	—			(50		)	(150		)	(175		)	(250		)	(225		)
Preferred stock dividends	(1		)	(1		)	(1		)	(1		)	(3		)	(3		)
Retained earnings, end of period	1,774			1,620			1,931			1,907			1,931			1,907

Total Shareholders’ Equity	$	4,268		$	4,069		$	4,425		$	4,356		$	4,425		$	4,356

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

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

STATEMENT OF INCOME

(Unaudited) (In millions)


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018
Operating Revenues:
Electric	$	442	$	449	$	452	$	448	$	1,305	$	1,333
Natural gas	320		311		112		116		568		569
Total operating revenues	762		760		564		564		1,873		1,902
Operating Expenses:
Purchased power	105		124		101		105		284		334
Natural gas purchased for resale	134		147		25		25		195		215
Other operations and maintenance	191		199		193		195		580		590
Depreciation and amortization	101		90		102		94		304		278
Taxes other than income taxes	45		41		33		32		110		108
Total operating expenses	576		601		454		451		1,473		1,525
Operating Income	186		159		110		113		400		377
Other Income, Net	11		6		13		11		39		30
Interest Charges	37		37		38		38		111		112
Income Before Income Taxes	160		128		85		86		328		295
Income Taxes	39		32		20		23		79		73
Net Income	121		96		65		63		249		222
Preferred Stock Dividends	1		1		—		—		2		2
Net Income Available to Common Shareholder	$	120	$	95	$	65	$	63	$	247	$	220

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

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

BALANCE SHEET

(Unaudited) (In millions)


	March 31, 2019		December 31, 2018		September 30, 2019		December 31, 2018
ASSETS
Current Assets:
Cash and cash equivalents	$	—	$	—	$	—	$	—
Accounts receivable – trade (less allowance for doubtful accounts of $12 and $11, respectively)	315		224
Accounts receivable – trade (less allowance for doubtful accounts of $11 and $11, respectively)					222		224
Accounts receivable – affiliates	18		21		38		21
Unbilled revenue	110		140		117		140
Miscellaneous accounts receivable	34		40		16		40
Inventories	73		125		132		125
Current regulatory assets	92		110		58		110
Other current assets	15		16		26		16
Total current assets	657		676		609		676
Property, Plant, and Equipment, Net	9,347		9,198
Property and Plant, Net					9,819		9,198
Investments and Other Assets:
Goodwill	411		411		411		411
Regulatory assets	776		759		796		759
Other assets	303		275		311		275
Total investments and other assets	1,490		1,445		1,518		1,445
TOTAL ASSETS	$	11,494	$	11,319	$	11,946	$	11,319
LIABILITIES AND SHAREHOLDERS’ EQUITY
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Short-term debt	$	126	$	72	$	310	$	72
Accounts and wages payable	242		302		247		302
Accounts payable – affiliates	63		58		67		58
Taxes accrued	19		23
Interest accrued	27		31
Customer deposits	73		76		71		76
Current environmental remediation	45		42		56		42
Current regulatory liabilities	79		62		49		62
Other current liabilities	129		130		176		184
Total current liabilities	803		796		976		796
Long-term Debt, Net	3,296		3,296		3,279		3,296
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes, net	1,151		1,119
Accumulated deferred income taxes and investment tax credits, net					1,180		1,119
Regulatory liabilities	1,765		1,741		1,884		1,741
Pension and other postretirement benefits	281		280		261		280
Environmental remediation	101		109		85		109
Other deferred credits and liabilities	203		204		260		204
Total deferred credits and other liabilities	3,501		3,453		3,670		3,453
Commitments and Contingencies (Notes 2, 8, and 9)
Shareholders’ Equity:
Commitments and Contingencies (Notes 2, 8 and 9)
Shareholders' Equity:
Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding	—		—		—		—
Other paid-in capital	2,173		2,173		2,173		2,173
Preferred stock	62		62		62		62
Retained earnings	1,659		1,539		1,786		1,539
Total shareholders’ equity	3,894		3,774
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	11,494	$	11,319
Total shareholders' equity					4,021		3,774
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY					$	11,946	$	11,319

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

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

STATEMENT OF CASH FLOWS

(Unaudited) (In millions)


	Three Months Ended March 31,						Nine Months Ended September 30,
	2019			2018			2019			2018
Cash Flows From Operating Activities:
Net income	$	121		$	96		$	249		$	222
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	100			90			303			278
Amortization of debt issuance costs and premium/discounts	3			3			9			10
Deferred income taxes and investment tax credits, net	24			9			42			56
Other	(1		)	(2		)	8			5
Changes in assets and liabilities:
Receivables	(56		)	(34		)	18			21
Inventories	52			63			(7		)	(7		)
Accounts and wages payable	(34		)	(52		)	(48		)	(44		)
Taxes accrued	12			1			14			(40		)
Regulatory assets and liabilities	18			(16		)	147			63
Assets, other	3			2			(15		)	—
Liabilities, other	(12		)	(36		)	13			(40		)
Pension and other postretirement benefits	(3		)	6			(27		)	(8		)
Net cash provided by operating activities	227			130			706			516
Cash Flows From Investing Activities:
Capital expenditures	(267		)	(300		)	(900		)	(947		)
Other							(3		)	10
Net cash used in investing activities	(267		)	(300		)	(903		)	(937		)
Cash Flows From Financing Activities:
Dividends on preferred stock	(1		)	(1		)	(2		)	(2		)
Short-term debt, net	54			162			237			46
Money pool borrowings, net							—			45
Maturities of long-term debt							—			(144		)
Issuances of long-term debt							—			430
Debt issuance costs							—			(5		)
Capital contribution from parent	—			20			—			80
Other							(1		)	1
Net cash provided by financing activities	53			181			234			451
Net change in cash, cash equivalents, and restricted cash	13			11			37			30
Cash, cash equivalents, and restricted cash at beginning of year	80			41
Cash, cash equivalents and restricted cash at beginning of year							80			41
Cash, cash equivalents, and restricted cash at end of period	$	93		$	52		$	117		$	71

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

AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)	AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)						AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF SHAREHOLDERS’ EQUITY (Unaudited) (In millions)

	Three Months Ended March 31,						Three Months Ended September 30,				Nine Months Ended September 30,
	2019			2018			2019		2018		2019			2018
Common Stock	$	—		$	—		$	—	$	—	$	—		$	—

Other Paid-in Capital:
Beginning of year	2,173			2,013
Beginning of period							2,173		2,093		2,173			2,013
Capital contribution from parent	—			20			—		—		—			80
Other paid-in capital, end of period	2,173			2,033			2,173		2,093		2,173			2,093

Preferred Stock	62			62
Preferred Stock:							62		62		62			62

Retained Earnings:
Beginning of year	1,539			1,235
Beginning of period							1,721		1,392		1,539			1,235
Net income	121			96			65		63		249			222
Preferred stock dividends	(1		)	(1		)	—		—		(2		)	(2		)
Retained earnings, end of period	1,659			1,330			1,786		1,455		1,786			1,455

Total Shareholders’ Equity	$	3,894		$	3,425		$	4,021	$	3,610	$	4,021		$	3,610

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

AMEREN CORPORATION (Consolidated)

UNION ELECTRIC COMPANY (d/b/a Ameren Missouri)

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

COMBINED NOTES TO FINANCIAL STATEMENTS

(Unaudited)

~~March 31,~~September 30, 2019

NOTE 1 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

General

Ameren, headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. Ameren has other subsidiaries that conduct other activities, such as providing shared services.

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

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

ATXI operates a FERC rate-regulated electric transmission business. ATXI ~~placed the Spoon River project in service in February 2018, and~~ is developing ~~two additional~~the MISO-approved ~~electric transmission projects, the~~ Illinois Rivers and Mark Twain electric transmission projects.

Ameren’s financial statements are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been ~~eliminated.~~ eliminated, except as disclosed in Note 8 – Related-party Transactions. Ameren Missouri and Ameren Illinois have no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.

Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair statement 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. The results of operations of an interim period may not give a true indication of results that may be expected for a full year. These financial statements should be read in conjunction with the financial statements and accompanying notes included in the Form 10-K.

Variable Interest Entities

As of ~~March 31,~~September 30, 2019, Ameren and Ameren Missouri had interests in unconsolidated variable interest entities that were established to construct wind generation facilities and, ultimately, sell those constructed facilities to Ameren Missouri. Neither Ameren nor Ameren Missouri are the primary beneficiary of these variable interest entities because neither has the power to direct matters that most significantly affect the entities' activities, which include designing, financing, and constructing the wind generation facilities. As a result, these variable interest entities have not been consolidated. As of ~~March 31,~~September 30, 2019, the maximum exposure to loss related to these variable interest entities was approximately ~~$16~~$12 million, which primarily represents ~~the portion of interconnection study~~legal costs ~~that may be incurred by Ameren and Ameren Missouri.~~incurred. The risk of a loss was assessed to be remote and, accordingly, Ameren and Ameren Missouri have not recognized a liability associated with any portion of the maximum exposure to loss. See Note 2 – Rate and Regulatory Matters for additional information on the agreements to acquire these wind generation facilities.

As of ~~March 31,~~September 30, 2019, and December 31, 2018, Ameren had unconsolidated variable interests as a limited partner in various equity method investments, totaling ~~$23~~$27 million and $22 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of ~~March 31,~~September 30, 2019, the maximum exposure to loss related to these variable interests is limited to the investment in these partnerships of ~~$23~~$27 million plus associated outstanding funding commitments of ~~$15~~$37 million.

Company-owned Life Insurance

Ameren and Ameren Illinois have company-owned life insurance, which is recorded at the net cash surrender value. The net cash surrender value is the amount that can be realized under the insurance policies at the balance sheet date. As of ~~March 31,~~September 30, 2019, the cash surrender value of company-owned life insurance at Ameren and Ameren Illinois was $258 million (December 31, 2018 – $244 million) and ~~$123~~$121 million (December 31, 2018 – $122 million), respectively, while total borrowings against the policies were ~~$113~~$114 million (December 31,

2018 – $113 million) at both Ameren and Ameren Illinois. Ameren and Ameren Illinois have the right to offset the borrowings

against the cash surrender value of the policies and, consequently, present the net asset in “Other assets” on their respective balance sheets.

Accounting and Reporting Developments

See Note 13 – Supplemental Information for additional information on our adoption of authoritative accounting guidance related to leases. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for additional information about recently issued authoritative accounting standards relating to the measurement of credit losses on financial instruments, fair value measurement disclosures, and defined benefit plan disclosures.

NOTE 2 – RATE AND REGULATORY MATTERS

Below is a summary of updates to significant regulatory proceedings and related lawsuits. See also Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K. 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.

Missouri

2019 Electric Service Regulatory Rate Review

decreased net energy costs of approximately $100 million otherwise subject to FAC recovery;

higher weather-normalized customer sales volumes, which reduced the rate request by approximately $55 million;

decreased expenses, other than net energy costs, of approximately $20 million, which includes a decrease to those expenses subject to regulatory recovery mechanisms and changes in amortization of regulatory assets and liabilities of approximately $80 million;

increased depreciation and amortization expense of approximately $115 million for new electric infrastructure investments, of which approximately $35 million reflects higher depreciation rates and another $35 million would otherwise be deferred under PISA; and

an increase of approximately $60 million of pre-tax return on rate base, which includes both the debt and equity components, of which approximately $30 million would otherwise be deferred under PISA.

Ameren Missouri’s base rates for electric service, which were last reset on April 1, 2017, and adjusted by a July 2018 MoPSC order, are required to be reset at least every four years to allow for continued use of the FAC. This filing, which includes a request for continued use of the FAC, allows Ameren Missouri to meet that requirement while providing flexibility to time its next regulatory rate review to include wind generation investments expected to be made by the end of 2020.

Ameren Missouri also requested continued use of the regulatory recovery mechanisms for pension and postretirement benefits, uncertain income tax positions and certain excess deferred taxes that the MoPSC previously authorized in earlier electric rate orders.

The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by late April 2020 and new rates effective by late May 2020. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, when any rate change may go into effect, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient for Ameren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.

Wind Generation Facilities and RESRAM

In May 2019, Ameren Missouri entered into a build-transfer agreement ~~with a subsidiary of Enel Green Power North America, Inc.~~ to acquire, after construction, an up-to 300-megawatt wind generation facility to be located in northwestern Missouri. Ameren Missouri expects to file for a certificate of convenience and necessity with the MoPSC in May 2019. Final RTO interconnection costs are expected to be determined in June 2019, and a related RTO transmission interconnection agreement is expected in the fall of 2019.

facility. In 2018, Ameren Missouri entered into ~~two~~a build-transfer ~~agreements~~agreement to acquire, after construction, an up-to ~~400-megawatt~~400-megawatt wind generation ~~facility~~facility.The two build-transfer agreements, which are subject to customary contract terms and ~~an up-to 157-megawatt wind generation facility. In October 2018, the MoPSC issued an order approving a unanimous stipulation and agreement regarding a requested certificate~~ conditions, collectively represent approximately $1.2 billion of convenience and necessity for the up-to 400-megawatt facility. In March 2019, the MoPSC issued an order approving a nonunanimous stipulation and agreement regarding a requested certificate of convenience and necessity for the up-to 157-megawatt facility. Final MISO interconnection costs for the up-to 400-megawatt facility are expected to be determined in June 2019, and a related transmission interconnection agreement with the MISO is expected in the fall of 2019. Final MISO interconnection costs for the up-to 157-megawatt facility are expected to be determined in the fall of 2019, and a related transmission interconnection agreement with the MISO is expected in early 2020.

~~All three facilities~~capital expenditures, are expected to be completed by the end of 2020, ~~which~~and would support Ameren Missouri’s compliance with the Missouri renewable energy standard. ~~Each acquisition~~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.The county zoning approval process for the Schuyler County portion of the 400-megawatt project is subject to ~~certain conditions, including~~litigation filed in August 2019, which is not expected to affect the ~~issuance~~completion of ~~a certificate of convenience and necessity~~the project by the ~~MoPSC for the up-to 300-megawatt facility, obtaining FERC approval for the up-to 157-megawatt~~end of 2020. The following table provides information with respect to each build-transfer agreement:



	Up-to 400-Megawatt Facility	Up-to 300-Megawatt Facility
Build-transfer agreement date	May 2018	May 2019
Wind facility developer	Terra-Gen, LLC	Invenergy Renewables, LLC^(a)
Location	Northeastern Missouri	Northwestern Missouri
Status of certificate of convenience and necessity from the MoPSC	Approved October 2018	Approved August 2019
Status of final interconnection costs	Received July 2019	Received July 2019
Status of RTO transmission interconnection agreement	Executed August 2019	Executed October 2019
Status of FERC approval	Received December 2018	Received October 2019
Expected completion date	By the end of 2020	By the end of 2020


(a)	In October 2019, Invenergy Renewables, LLC acquired the project from Enel North America, Inc.

In 2018, Ameren Missouri entered into a build-transfer agreement to acquire, after construction, a 157-megawatt wind generation facility. In July 2019, Ameren Missouri and the ~~up-to 300-megawatt facility, entering into an RTO transmission~~developer mutually agreed to terminate the project due to unacceptable interconnection ~~agreement at an acceptable cost for each facility,~~costs, which made the project uneconomic and ~~other customary contract terms and conditions.~~not in the best interest of Ameren Missouri’s customers. Abandonment costs incurred as a result of terminating the project were immaterial to Ameren Missouri.

~~The three build-transfer agreements collectively represent approximately $1.4 billion of capital expenditures expected in 2020.~~

In January 2019, the MoOPC filed an appeal with the Missouri Court of Appeals, Western District, challenging the MoPSC’s December 2018 order allowing Ameren Missouri to recover, through the RESRAM, the 15% of depreciation expense and weighted average cost of capital return not recovered under PISA. ~~Ameren~~In October 2019, the Missouri ~~expects~~Court of Appeals, Western District upheld the MoPSC’s order. In November 2019, the MoOPC filed a ~~decision by~~request for appeal of the ~~end of 2019.~~MoPSC’s order to the Missouri Supreme Court. The RESRAM is designed to mitigate the impacts of regulatory lag for the cost of compliance with renewable energy standards, including recovery of investments in wind and other renewable energy generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA. ~~RESRAM regulatory assets earn carrying costs at short-term interest rates.~~

MEEIA

As a result of MoPSC orders issued in September 2017, October 2018, January 2019, and ~~January~~September 2019 related to performance incentives for the MEEIA 2013 and MEEIA 2016 programs, Ameren Missouri recognized ~~gains~~revenues of $20 million and $5 million during the ~~three months ended March 31,~~first quarter of 2019 and 2018, ~~respectively.~~respectively, and $18 million in the third quarter of 2019.

Request for Deferral of Maintenance Expenses Related to Scheduled Callaway Refueling and Maintenance Outages

In October 2019, Ameren Missouri filed a request with the MoPSC for deferral accounting treatment that would allow Ameren Missouri to defer and amortize maintenance expenses related to scheduled refueling and maintenance outages at its Callaway nuclear energy center. These expenses would be amortized over the period between refueling and maintenance outages, which is approximately 18 months. Ameren Missouri cannot predict the ultimate outcome of this regulatory proceeding. If the request is approved prior to the fall 2020 refueling and maintenance outage, Ameren Missouri would defer the maintenance expenses incurred related to the outage as a regulatory asset and begin to amortize those expenses after completion of the outage.

2018 Natural Gas Delivery Service Regulatory Rate Review

In December 2018, Ameren Missouri filed a request with the MoPSC to increase its annual revenues for natural gas delivery ~~service by approximately $4 million, prior to~~service.In August 2019, the interim rate reduction discussed below. The natural gas delivery service rate increase request is based on a 10.30% return on equity, a capital structure composed of 51.84% common equity, a rate base of $259 million, and a test year ended June 30, 2018, with certain pro-forma adjustments through the anticipated true-up date of May 31, 2019. In December 2018, the MoPSC

issued an order approving a stipulation and agreement ~~for an interim rate reduction of $2 million~~ to reflect cost of service updates including the reduction in the federal corporate income tax rate and the amortization of excess deferred taxes as a result of the TCJA. As a result of the interim rate reduction,decrease Ameren ~~Missouri's requested~~Missouri’s annual revenues ~~reflect~~for natural gas delivery service by$1 million. The decrease in annual rates is based on a $6return on common equity range of 9.4% to 9.95% and a capital structure composed of 52.0% common equity, which was Ameren Missouri’s capital structure as of May 31, 2019. This order allows for the use of ISRS, which will be calculated using an ROE of 9.725%. The order represents a $1 million increase to Ameren Missouri’s annual revenues for natural gas delivery service from interim ~~rates. The interim rate reduction became effective January 2, 2019, and will continue until new~~ rates, ~~are~~which were approved by the MoPSC in ~~this regulatory rate review. In April 2019, the MoPSC staff recommended a $1 million increase to interim~~December 2018.The new rates ~~based on a 9.5% return on equity and a 50% ceiling on the common equity ratio.~~became effective September 1, 2019.

Illinois

Electric Distribution Service Rates

In April 2019, Ameren Illinois filed its annual electric distribution service formula rate update to establish the revenue requirement to be used for 2020 rates with the ICC. Pending ICC approval, this update filing will result in a $7 million decrease in Ameren Illinois’ electric distribution service rates, beginning in January 2020.This update reflects an increase to the annual formula rate based on 2018 actual costs and expected net plant additions for 2019, and an increase to include the 2018 revenue requirement reconciliation adjustment. It also reflects a decrease for the conclusion of the 2017 revenue requirement reconciliation adjustment, which will be fully collected from customers in 2019, consistent with the ICC’s November 2018 annual update filing order. It also reflects an increase to the annual formula rate based on 2018 actual costs and expected net plant additions for 2019, and an increase to include the 2018 revenue requirement reconciliation adjustment. In August 2019, the ICC staff submitted an updated calculation

of the revenue requirement included in Ameren Illinois’ filing, recommending an amount comparable to that included in Ameren Illinois’ filing. In October 2019, the administrative law judges issued a proposed order consistent with Ameren Illinois’ filing. An ICC decision in this proceeding is expected by December 2019. ~~As of March 31,~~

Electric Customer Energy-Efficiency Investments

In May 2019, Ameren Illinois ~~had recorded a regulatory asset of $41 million~~filed its annual electric customer energy-efficiency formula rate update to ~~reflect the difference between Ameren Illinois’ estimate of its 2019 revenue requirement and~~establish the revenue requirement ~~reflected~~to be used for 2020 rates with the ICC. This rate update is based on an 8.9% return on common equity, a capital structure composed of 50% common equity, and $205 million of net electric customer energy-efficiency investments. Pending ICC approval, this update filing will result in 2020 electric customer energy-efficiency rates ~~including interest.~~of $44 million, which represents an increase of $10 million from 2019 rates. In September 2019, the ICC staff submitted an updated calculation of the revenue requirement included in Ameren Illinois’ filing, recommending an amount comparable to that included in Ameren Illinois’ filing. An ICC decision in this proceeding is expected by December 2019.

ATXI’s Illinois Rivers Project

In August 2017, the Illinois Circuit Court for Edgar County dismissed several of ATXI’s condemnation cases related to the one remaining line segment to be completed in the Illinois Rivers project. These cases had been filed to obtain easements and rights of way necessary to complete the line segment. The court found that required notice was not given to the relevant landowners during the underlying ICC proceeding. Upon appeal, in October 2018, the Illinois Supreme Court reversed the Illinois Circuit Court for Edgar County’s decision and remanded the case for further proceedings. In ~~December 2018, the Illinois Supreme Court issued an order to stay its October 2018 ruling. In~~ February 2019, the landowners filed an appeal with the United States Supreme Court, which was denied in April 2019. In the second quarter of 2019, ~~ATXI intends to seek to reinstate~~at ATXI’s request, the Illinois Circuit Court for Edgar County reinstated the condemnation cases that were previously dismissed. ATXI expects to complete the line segment in 2020. The estimated line segment capital expenditure investment is approximately $81 million, of which ~~$38~~$39 million was invested as of ~~March 31,~~September 30, 2019. ~~The other eight line segments of the Illinois Rivers project have already been completed and placed in-service and are not affected by these proceedings.~~

Federal

FERC Complaint Cases

In November 2013, a customer group filed a complaint case with the FERC seeking a reduction in the allowed base return on common equity for FERC-regulated transmission rate base under the MISO tariff from 12.38% to 9.15%. In September 2016, the FERC issued an order in the November 2013 complaint case, which lowered the allowed base return on common equity to 10.32%, or a 10.82% total allowed return on common equity with the inclusion of a 50 basis point incentive adder for participation in an RTO, effective since September 2016. The 10.82% allowed return on common equity may be replaced prospectively after the FERC issues a final order in the February 2015 complaint case, discussed below.

Since the maximum FERC-allowed refund period for the November 2013 complaint case ended in February 2015, another customer complaint case was filed in February 2015. MISO transmission owners subsequently filed a motion to dismiss the February 2015 complaint, as discussed below. The February 2015 complaint case seeks a further reduction in the allowed base return on common equity for FERC-regulated transmission rate base under the MISO tariff. In June 2016, an administrative law judge issued an initial decision in the February 2015 complaint case. If approved by the FERC, it would lower the allowed base return on common equity for the 15-month period of February 2015 to May 2016 to 9.70%, or a 10.20% total allowed return on equity with the inclusion of a 50 basis point incentive adder for participation in an RTO. It would also require customer refunds, with interest, for that 15-month period. A final FERC order would also establish the allowed return on common equity that will apply prospectively from the effective date of such order, replacing the current 10.82% total return on common equity. In April 2017, the United States Court of Appeals for the District of Columbia Circuit vacated and remanded to the FERC an order in an unrelated case in which the FERC established the allowed base return on common equity methodology subsequently used in the two MISO complaint cases described above. In October 2018, the FERC issued an order in an the unrelated case that proposed a new methodology for determining the base return on equity, ~~and~~which required further briefs from the participants. In November 2018, the FERC issued an order related to the February 2015 complaint case and the September 2016 order, which required participants to file briefs in February 2019 regarding the FERC’s proposed methodology for determining the base return on common equity, including whether and how to apply the proposed methodology to the two MISO complaint cases. In March 2019, the FERC issued separate Notices of Inquiry regarding its allowed base return on common equity policy and its transmission incentives ~~policy, with~~policy. Initial comments were due inby June 2019, and reply comments were due by late August 2019. The Notice of Inquiry addressing the FERC’s return on common equity policy, among other things, ~~broadens~~broadened the ability to comment on the new methodology

beyond electric utilities that are participants in the complaint ~~cases, and the~~cases. The transmission incentives Notice of Inquiry iswas open for ~~industry~~ comment on the FERC’s transmission incentive policy, including incentive adders to the return on common equity. Ameren is unable to predict the ultimate impact of the proposed methodology on these complaint cases or the Notices of Inquiry at this time.As the FERC is under no deadline to issue a final order, the timing of the final order in the February 2015 complaint case and any potential impact to the amounts refunded as a result of the September 2016 order is uncertain.

In September 2017, MISO transmission owners, including Ameren Missouri, Ameren Illinois, and ATXI, filed a motion to dismiss the February 2015 complaint case with the FERC. The MISO transmission owners maintain that the February 2015 complaint was predicated on

the now superseded 12.38% allowed base return on common equity and is therefore inapplicable given the current 10.32% allowed base return on common equity. The MISO transmission owners further maintain that the current 10.32% allowed base return on common equity has not been proven to be unjust and unreasonable based on information provided, including the base return on common equity methodology ranges set forth in the February 2015 complaint case and in the initial decision issued by an administrative law judge in June 2016. Additionally, the MISO transmission owners maintain that the February 2015 complaint should be dismissed because the approach utilized in the case to assert that a return on common equity was unjust and unreasonable was insufficient. That same approach was rejected by the United States Court of Appeals for the District of Columbia Circuit in an unrelated case, as discussed above. The FERC is under no deadline to issue an order on this motion.

As of ~~March 31,~~September 30, 2019, Ameren and Ameren Illinois had recorded current regulatory liabilities of ~~$44~~$46 million and ~~$26~~$27 million, respectively, to reflect the expected refunds, including interest, associated with the reduced allowed return on common equity in the initial decision in the February 2015 complaint case. Ameren Missouri does not expect that a reduction in the FERC-allowed base return on common equity would be material to its results of operations, financial position, or liquidity.

NOTE 3 – SHORT-TERM DEBT AND LIQUIDITY

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

The Missouri Credit Agreement and the Illinois Credit Agreement were not utilized for direct borrowings during the ~~three~~nine months ended ~~March 31,~~September 30, 2019, but were used to support commercial paper issuances and to issue letters of credit. Based on commercial paper outstanding and letters of credit issued under the Credit Agreements, the aggregate credit capacity available under the Credit Agreements to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, at ~~March 31,~~September 30, 2019, was ~~$1.3~~$1.6 billion. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of ~~March 31,~~September 30, 2019. As of ~~March 31,~~September 30, 2019, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were ~~54%~~53%, 48%, and 47% for Ameren, Ameren Missouri, and Ameren Illinois, respectively.

Commercial Paper

The following table presents commercial paper outstanding, net of issuance discounts, as of ~~March 31,~~September 30, 2019, and December 31, 2018:


	March 31, 2019		December 31, 2018		September 30, 2019		December 31, 2018
Ameren (parent)	$	618	$	470	$	90	$	470
Ameren Missouri	55		55		144		55
Ameren Illinois	126		72		310		72
Ameren consolidated	$	799	$	597	$	544	$	597

The following table summarizes the borrowing activity and relevant interest rates under Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper programs for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Ameren (parent)			Ameren Missouri			Ameren Illinois			Ameren Consolidated			Ameren (parent)			Ameren Missouri			Ameren Illinois				Ameren Consolidated
2019
Average daily commercial paper outstanding at par value	$	480		$	246		$	89		$	815		$	532		$	141		$	147			$	821
Weighted-average interest rate	2.87		%	2.84		%	2.76		%	2.85		%	2.70		%	2.73		%	2.58		%		2.68		%
Peak commercial paper during period at par value^(a)	$	618		$	549		$	130		$	1,113		$	651		$	549		$	310			$	1,113
Peak interest rate	3.10		%	2.97		%	2.90		%	3.10		%	3.80		%	2.97		%	5.00		%	^(b)	5.00		%	^(b)
2018
Average daily commercial paper outstanding at par value	$	378		$	213		$	137		$	728		$	431		$	81		$	117			$	629
Weighted-average interest rate	1.90		%	1.88		%	1.96		%	1.90		%	2.23		%	1.94		%	2.21		%		2.18		%
Peak commercial paper during period at par value^(a)	$	454		$	282		$	238		$	960		$	543		$	481		$	442			$	1,295
Peak interest rate	2.35		%	2.40		%	2.55		%	2.55		%	2.45		%	2.42		%	2.55		%		2.55		%


(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 third quarter of 2019, Ameren’s and Ameren Illinois’ peak interest rate was affected by temporary disruptions in the commercial paper market.

Money Pools

Ameren has money pool agreements with and among its subsidiaries to coordinate and provide for certain short-term cash and working capital requirements. The average interest rate for borrowings under the money pool for the three and nine months ended ~~March 31,~~September 30, 2019, was 2.40% and ~~2018, was 2.87%~~2.67%, respectively (2018 – 2.00% and ~~1.90%~~2.02%, ~~respectively.~~respectively). See Note 8 – Related-party Transactions for the amount of interest income and expense from the money pool arrangements recorded by the Ameren Companies for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018.

NOTE 4 – LONG-TERM DEBT AND EQUITY FINANCINGS

Ameren

For the three and nine months ended ~~March 31,~~September 30, 2019, Ameren issued a total of ~~0.3~~0.2 million and 0.7 million shares of common stock under its DRPlus and 401(k) plan, and received proceeds of ~~$19 million.~~$17 million and $54 million, respectively. In addition, in the first quarter of 2019, Ameren issued 0.8 million shares of common stock valued at $54 million upon the vesting of stock-based compensation.

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 price was initially $74.18 per share. The initial forward sale price is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75 basis points, and will be subject to decrease on certain dates specified in the forward sale agreement by specified amounts related to expected dividends on shares of the common stock during the term of the forward sale agreement. If the overnight bank funding rate is less than the spread on any day, the interest rate factor will result in a reduction of the forward sale price.

The forward sale agreement will be physically settled unless Ameren elects to settle in cash or to net share settle. At September 30, 2019, Ameren could have settled the forward sale agreement with physical delivery of 7.5 million shares of common stock to the counterparty in exchange for cash of $557 million. The forward sale agreement could also have been settled at September 30, 2019, with delivery of approximately $47 million of cash or approximately 0.6 million shares of common stock to the counterparty, if Ameren had elected to net cash or net share settle, respectively.

The forward sale agreement has been classified as an equity transaction because it is indexed to Ameren’s common stock, physical settlement is within Ameren’s control, and the other requirements necessary for equity classification were met. As a result of the equity classification, no gain or loss will be recognized within earnings due to subsequent changes in the fair value of the forward sale agreement. If the average price of Ameren’s common stock exceeds the adjusted forward sale price during a quarterly period, the forward sale agreement could have a dilutive effect on earnings per share.

In September 2019, Ameren issued $450 million of 2.50% senior unsecured notes due September 2024, with interest payable semiannually on March 15 and September 15, beginning March 15, 2020. Ameren received net proceeds of $447 million, which were used to repay outstanding short-term debt.

Ameren Missouri

In March 2019, Ameren Missouri issued $450 million of 3.50% first mortgage bonds due March 2029, with interest payable semiannually on March 15 and September 15 of each year, beginning September 15, 2019. Ameren Missouri received net proceeds of $447 million, which were used to repay outstanding short-term debt, including short-term debt that Ameren Missouri incurred in connection with the repayment of $329 million of its 6.70% senior secured notes that matured February 1, 2019.

In June and July 2019, all of the 1992 Series bonds, 1998 Series A bonds, 1998 Series B bonds, and 1998 Series C bonds issued by the Missouri Environmental Improvement and Energy Resources Authority on behalf of Ameren Missouri were subject to purchase in lieu of redemption or a mandatory tender as a result of a change in the method of determining the interest rates on the bonds. The interest rate method of each of the series of bonds, as well as Ameren Missouri’s first mortgage bonds that collaterally secure each of the series of bonds, was changed from a variable rate to a fixed rate. Upon the change in the method of determining the interest rate, the bonds, totaling $207 million, were remarketed to new investors. The following table provides additional information on the bonds:



	1992 Series	1998 Series A	1998 Series B	1998 Series C
Transaction month	June 2019	July 2019	July 2019	June 2019
Principal amount	$47	$60	$50	$50
Fixed interest rate	1.60%	2.90%	2.90%	2.75%
Variable interest rate ^(a)	2.36%	3.35%	3.34%	3.83%
Maturity	December 2022	September 2033	September 2033	September 2033
Interest payment dates	June 1 and December 1	March 1 and September 1	March 1 and September 1	March 1 and September 1
Initial interest payment date	December 2019	September 2019	September 2019	September 2019


(a)	Represents the variable interest rate of the bonds effective prior to the change in method of determining the interest rate.

In October 2019, Ameren Missouri issued $330 million of 3.25% first mortgage bonds due October 2049, with interest payable semiannually on April 1 and October 1 of each year, beginning April 1, 2020. Ameren Missouri received net proceeds of $326 million, which were used to repay $244 million of its 5.10% senior unsecured notes due October 1, 2019, with the remaining proceeds used to repay a portion of its short-term debt.

In October 2019, Ameren Missouri redeemed the remaining amount outstanding of its 5.45% first mortgage bonds due 2028 for less than $1 million.

Ameren Illinois

In 2006, Ameren Illinois purchased all $17 million of the 1993 Series B-1 bonds due 2028 issued by the Illinois Finance Authority on behalf of Ameren Illinois pursuant to a mandatory tender. Ameren Illinois’ 1993 Series B-1 senior unsecured notes due 2028 were not extinguished and remained as “Long-term debt, net” on Ameren’s and Ameren Illinois’ balance sheets. In September 2019, Ameren Illinois exchanged its bond investments for the extinguishment of its senior unsecured notes.

In September 2019, Ameren Illinois redeemed the remaining amount outstanding of its 5.70% first mortgage bonds due 2024 for less than $1 million. Additionally, in October 2019, Ameren Illinois redeemed the remaining amount outstanding of its 5.90% first mortgage bonds due 2023 for less than $1 million. Following the redemption of the 5.90% first mortgage bonds, Ameren Illinois collaterally secured its 6.70% senior secured notes due 2036 with first mortgage bonds issued under its 1992 mortgage indenture.

Indenture Provisions and Other Covenants

See Note 5 – Long-Term Debt and Equity Financings under Part II, Item 8, in the Form 10-K for a description of our indenture provisions and other covenants, as well as restrictions on the payment of dividends. At ~~March 31,~~September 30, 2019, the Ameren Companies were in compliance with the provisions and covenants contained in their indentures and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreement.

Off-balance-sheet Arrangements

At ~~March 31,~~September 30, 2019, none of the Ameren Companies had any significant off-balance-sheet financing arrangements, other than variable interest entities, letters of credit, and Ameren (parent) guarantee arrangements on behalf of its subsidiaries. See Note 1 – Summary of Significant Accounting Policies for further detail concerning variable interest entities.

NOTE 5 – OTHER INCOME, NET

The following table presents the components of “Other Income, Net” in the Ameren Companies’ statements of income for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:

Three Months
2019 2018
Ameren:



	Three Months						Nine Months
	2019			2018			2019			2018
Ameren:
Allowance for equity funds used during construction	$	7		$	11		$	20		$	25
Interest income on industrial development revenue bonds	6			6			19			19
Other interest income	2			2			6			6
Non-service cost components of net periodic benefit income^(a)	23			17			67			52
Miscellaneous income	2			2			6			5
Donations	(1		)	(4		)	(8		)	(15		)
Miscellaneous expense	(5		)	(2		)	(11		)	(8		)
Total Other Income, Net	$	34		$	32		$	99		$	84



	Three Months						Nine Months
	2019			2018			2019			2018
Ameren Missouri:
Allowance for equity funds used during construction	$	6		$	8		$	14		$	19
Interest income on industrial development revenue bonds	6			6			19			19
Other interest income	—			1			—			2
Non-service cost components of net periodic benefit income^(a)	4			4			13			13
Miscellaneous income	2			2			4			3
Donations	(1		)	(3		)	(3		)	(6		)
Miscellaneous expense	(2		)	(2		)	(4		)	(5		)
Total Other Income, Net	$	15		$	16		$	43		$	45
Ameren Illinois:
Allowance for equity funds used during construction	$	1		$	3		$	6		$	6
Interest income	1			1			5			4
Non-service cost components of net periodic benefit income	12			8			36			25
Miscellaneous income	1			1			3			3
Donations	—			—			(5		)	(5		)
Miscellaneous expense	(2		)	(2		)	(6		)	(3		)
Total Other Income, Net	$	13		$	11		$	39		$	30

Three Months
2019 2018
Allowance for equity funds used during construction $ 6
$ 5

Interest income on industrial development revenue bonds 6
6

Other interest income 2
2

Non-service cost components of net periodic benefit income^(a)
22
16

Miscellaneous income 2
1

Donations (6 ) (5 )
Miscellaneous expense (3 ) (2 )
Total Other Income, Net $ 29
$ 23

Ameren Missouri:
Allowance for equity funds used during construction $ 4
$ 4

Interest income on industrial development revenue bonds 6
6

Non-service cost components of net periodic benefit income^(a)
4
5

Miscellaneous income 1
1

Donations (2 ) (1 )
Miscellaneous expense (1 ) (2 )
Total Other Income, Net $ 12
$ 13

Ameren Illinois:
Allowance for equity funds used during construction $ 2
$ 1

Interest income 2
2

Non-service cost components of net periodic benefit income 12
7

Miscellaneous income 1
—

Donations (4 ) (4 )
Miscellaneous expense (2 ) —

Total Other Income, Net $ 11
$ 6

(a)

For the three and nine months ended ~~March 31,~~September 30, 2019, ~~and 2018,~~ the non-service cost components of net periodic benefit income were partially offset by a $7 million and $4$22 million deferral, 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.~~rates (2018 – $5 million and $13 million, respectively).

NOTE 6 – DERIVATIVE FINANCIAL INSTRUMENTS

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

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

market values of natural gas 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.

The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of March 31, 2019, and December 31, 2018. As of March 31, 2019, these contracts extended through October 2022, October 2023, and May 2032 for fuel oils, natural gas, and power, respectively.

Quantity (in millions)
2019 2018
Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren
Fuel oils (in gallons)^(a)
65
—
65
66
—
66
Natural gas (in mmbtu) 18
156
174
19
154
173
Power (in megawatthours) 2
8
10
1
8
9


~~(a)~~	~~Consists of ultra-low-sulfur diesel products.~~

All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. ~~See Note 7 – Fair Value Measurements for discussion of our methods of assessing the fair value of derivative instruments.~~ Many of our physical contracts, such as our purchased power contracts, qualify for the NPNS exception to derivative accounting rules. The revenue or expense on NPNS contracts is recognized at the contract price upon physical delivery. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting.

If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether the resulting gains or losses qualify for regulatory deferral. Derivative contracts that qualify for regulatory deferral are recorded at fair value, with changes in fair value recorded as regulatory assets or liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and liabilities are probable of recovery, or refund, through future rates charged to customers. Regulatory assets and liabilities are amortized to operating income as related losses and gains are reflected in rates charged to customers. Therefore, gains and losses on these derivatives have no effect on operating income. As of ~~March 31,~~September 30, 2019, and December 31, 2018, all contracts that met the definition of a derivative and were not eligible for the NPNS exception received regulatory deferral.

The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of September 30, 2019, and December 31, 2018. As of September 30, 2019, these contracts extended through October 2022, March 2024, and May 2032 for fuel oils, natural gas, and power, respectively.



	Quantity (in millions)
	2019			2018
Commodity	Ameren Missouri	Ameren Illinois	Ameren	Ameren Missouri	Ameren Illinois	Ameren
Fuel oils (in gallons)^(a)	63	—	63	66	—	66
Natural gas (in mmbtu)	20	142	162	19	154	173
Power (in megawatthours)	4	8	12	1	8	9


(a)	Consists of ultra-low-sulfur diesel products.

The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of ~~March 31,~~September 30, 2019, and December 31, 2018:


			March 31, 2019					December 31, 2018									September 30, 2019					December 31, 2018
	Balance Sheet Location		Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri		Ameren Illinois		Ameren	Balance Sheet Location		Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri		Ameren Illinois		Ameren
Fuel oils	Other current assets	$	5	$	—	$	5		$	3	$	—	$	3	Other current assets	$	4	$	—	$	4		$	3	$	—	$	3
	Other assets		4		—		4			5		—		5	Other assets		2		—		2			5		—		5
Natural gas	Other current assets		—		3		3			—		1		1	Other current assets		—		2		2			—		1		1
	Other assets		—		3		3			—		2		2	Other assets		—		1		1			—		2		2
Power	Other current assets		1		—		1			4		—		4	Other current assets		8		—		8			4		—		4
	Other assets		1		—		1			—		—		—	Other assets		4		—		4			—		—		—
	Total assets	$	11	$	6	$	17		$	12	$	3	$	15	Total assets	$	18	$	3	$	21		$	12	$	3	$	15
Fuel oils	Other current liabilities	$	3	$	—	$	3		$	4	$	—	$	4	Other current liabilities	$	7	$	—	$	7		$	4	$	—	$	4
	Other deferred credits and liabilities		4		—		4			9		—		9	Other deferred credits and liabilities		5		—		5			9		—		9
Natural gas	Other current liabilities		2		6		8			4		8		12	Other current liabilities		3		12		15			4		8		12
	Other deferred credits and liabilities		1		4		5			1		6		7	Other deferred credits and liabilities		1		7		8			1		6		7
Power	Other current liabilities		2		14		16			4		14		18	Other current liabilities		3		15		18			4		14		18
	Other deferred credits and liabilities		—		170		170			—		169		169	Other deferred credits and liabilities		1		189		190			—		169		169
	Total liabilities	$	12	$	194	$	206		$	22	$	197	$	219	Total liabilities	$	20	$	223	$	243		$	22	$	197	$	219

The Ameren Companies elect to present the fair value amounts of derivative assets and derivative liabilities subject to an enforceable master netting arrangement or similar agreement at the gross amounts on the balance sheet. However, if the gross amounts recognized on the balance sheet were netted with derivative instruments and cash collateral received or posted, the net amounts would not be materially different from the gross amounts at ~~March 31,~~September 30, 2019, and December 31, 2018.

~~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 NPNS and other accrual contracts. These exposures are calculated on a gross basis, which include affiliate exposure not eliminated at the consolidated Ameren level. As of ~~March 31,~~September 30, 2019, if counterparty groups were to fail completely to perform on contracts, the Ameren Companies’ maximum exposure related to derivative assets would have been immaterial with or without consideration of the application of master netting arrangements or similar agreements and collateral held.

~~Derivative Instruments with Credit Risk-related Contingent Features~~

~~Our commodity contracts~~Certain of our derivative instruments contain collateral provisions tied to the Ameren Companies’ credit ratings. If our credit ratings were downgraded below investment grade, or if a counterparty with reasonable grounds for uncertainty regarding our ability to satisfy an obligation requested adequate assurance of performance, additional collateral postings might be required. The ~~following table presents, as~~additional collateral required is the net liability position allowed under master netting arrangements or similar agreements, assuming (1) the credit risk-related contingent features underlying these arrangements were triggered and, (2) those counterparties with rights to do so requested collateral. As of ~~March 31,~~September 30, 2019, the aggregate fair value of ~~all~~ derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require. The additional collateral required is the net liability position allowed under the master netting arrangements or similar agreements, assuming (1) the credit risk-related contingent features underlying these arrangementsrequire were ~~triggered on March 31, 2019,~~each immaterial to Ameren, Ameren Missouri, and ~~(2) those counterparties with rights to do so requested collateral.~~Ameren Illinois.

Aggregate Fair Value of
Derivative Liabilities^(a)

Cash
Collateral Posted

Potential Aggregate Amount of
Additional Collateral Required^(b)
Ameren Missouri $ 64
$ 4
$ 58
Ameren Illinois 39
—
29
Ameren $ 103
$ 4
$ 87


~~(a)~~	~~Before consideration of master netting arrangements or similar agreements and including NPNS and other accrual contract exposures.~~


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

NOTE 7 – FAIR VALUE MEASUREMENTS

Fair value is defined as the price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ~~Authoritative accounting guidance provides a~~Fair value measurements are classified in three levels based on the fair value hierarchy that prioritizes the inputs used to measure fair value. On a quarterly basis, all financial assets and liabilities carried at fair value are classified and disclosed in one of three hierarchy levels. Financial assets and liabilities are classified in their entirety according to the lowest level of input that is significant to the fair value measurement.as defined by GAAP. See Note 8 – Fair Value Measurements

under Part II, Item 8, of the Form 10-K for information related to hierarchy ~~levels.~~levels and valuation techniques.

We consider nonperformance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g., collateral). Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in the three and nine months ended ~~March 31,~~September 30, 2019 or 2018. At ~~March 31,~~September 30, 2019, and December 31, 2018, the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois.

The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of ~~March 31,~~September 30, 2019, and December 31, 2018:


		March 31, 2019									December 31, 2018										September 30, 2019									December 31, 2018
		Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total				Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total
Assets:	Assets:																			Assets:
Ameren	Ameren																			Ameren
	Derivative assets – commodity contracts^(a):																			Derivative assets – commodity contracts^(a):
	Fuel oils	$	2	$	—	$	7	$	9		$	1	$	—	$	7	$	8		Fuel oils	$	—	$	—	$	6	$	6		$	1	$	—	$	7	$	8
	Natural gas	—		3		3		6			—		2		1		3			Natural gas	—		—		3		3			—		2		1		3
	Power	—		—		2		2			—		1		3		4			Power	1		—		11		12			—		1		3		4
	Total derivative assets – commodity contracts	$	2	$	3	$	12	$	17		$	1	$	3	$	11	$	15		Total derivative assets – commodity contracts	$	1	$	—	$	20	$	21		$	1	$	3	$	11	$	15
	Nuclear decommissioning trust fund:																			Nuclear decommissioning trust fund:
	Equity securities:																			Equity securities:
	U.S. large capitalization	$	488	$	—	$	—	$	488		$	427	$	—	$	—	$	427		U.S. large capitalization	$	518	$	—	$	—	$	518		$	427	$	—	$	—	$	427
	Debt securities:																			Debt securities:
	U.S. Treasury and agency securities	—		151		—		151			—		148		—		148			U.S. Treasury and agency securities	—		136		—		136			—		148		—		148
	Corporate bonds	—		76		—		76			—		72		—		72			Corporate bonds	—		86		—		86			—		72		—		72
	Other	—		33		—		33			—		32		—		32			Other	—		50		—		50			—		32		—		32
	Total nuclear decommissioning trust fund	$	488	$	260	$	—	$	748	^(b)	$	427	$	252	$	—	$	679	^(b)	Total nuclear decommissioning trust fund	$	518	$	272	$	—	$	790	^(b)	$	427	$	252	$	—	$	679	^(b)
	Total Ameren	$	490	$	263	$	12	$	765		$	428	$	255	$	11	$	694		Total Ameren	$	519	$	272	$	20	$	811		$	428	$	255	$	11	$	694
Ameren Missouri	Ameren Missouri																			Ameren Missouri
	Derivative assets – commodity contracts^(a):																			Derivative assets – commodity contracts^(a):
	Fuel oils	$	2	$	—	$	7	$	9		$	1	$	—	$	7	$	8		Fuel oils	$	—	$	—	$	6	$	6		$	1	$	—	$	7	$	8
	Power	—		—		2		2			—		1		3		4			Power	1		—		11		12			—		1		3		4
	Total derivative assets – commodity contracts	$	2	$	—	$	9	$	11		$	1	$	1	$	10	$	12		Total derivative assets – commodity contracts	$	1	$	—	$	17	$	18		$	1	$	1	$	10	$	12
	Nuclear decommissioning trust fund:																			Nuclear decommissioning trust fund:
	Equity securities:																			Equity securities:
	U.S. large capitalization	$	488	$	—	$	��	$	488		$	427	$	—	$	—	$	427		U.S. large capitalization	$	518	$	—	$	—	$	518		$	427	$	—	$	—	$	427
	Debt securities:																			Debt securities:
	U.S. Treasury and agency securities	—		151		—		151			—		148		—		148			U.S. Treasury and agency securities	—		136		—		136			—		148		—		148
	Corporate bonds	—		76		—		76			—		72		—		72			Corporate bonds	—		86		—		86			—		72		—		72
	Other	—		33		—		33			—		32		—		32			Other	—		50		—		50			—		32		—		32
	Total nuclear decommissioning trust fund	$	488	$	260	$	—	$	748	^(b)	$	427	$	252	$	—	$	679	^(b)	Total nuclear decommissioning trust fund	$	518	$	272	$	—	$	790	^(b)	$	427	$	252	$	—	$	679	^(b)
	Total Ameren Missouri	$	490	$	260	$	9	$	759		$	428	$	253	$	10	$	691		Total Ameren Missouri	$	519	$	272	$	17	$	808		$	428	$	253	$	10	$	691
Ameren Illinois	Ameren Illinois																			Ameren Illinois
	Derivative assets – commodity contracts^(a):																			Derivative assets – commodity contracts^(a):
	Natural gas	$	—	$	3	$	3	$	6		$	—	$	2	$	1	$	3		Natural gas	$	—	$	—	$	3	$	3		$	—	$	2	$	1	$	3
Liabilities:	Liabilities:																			Liabilities:
Ameren	Ameren																			Ameren
	Derivative liabilities – commodity contracts^(a):																			Derivative liabilities – commodity contracts^(a):
	Fuel oils	$	1	$	—	$	6	$	7		$	2	$	—	$	11	$	13		Fuel oils	$	4	$	—	$	8	$	12		$	2	$	—	$	11	$	13
	Natural gas	—		10		3		13			—		15		4		19			Natural gas	2		17		4		23			—		15		4		19
	Power	—		—		186		186			—		1		186		187			Power	—		1		207		208			—		1		186		187
	Total Ameren	$	1	$	10	$	195	$	206		$	2	$	16	$	201	$	219		Total Ameren	$	6	$	18	$	219	$	243		$	2	$	16	$	201	$	219
Ameren Missouri
	Derivative liabilities – commodity contracts^(a):
	Fuel oils	$	1	$	—	$	6	$	7		$	2	$	—	$	11	$	13
	Natural gas	—		3		—		3			—		5		—		5
	Power	—		—		2		2			—		1		3		4
	Total Ameren Missouri	$	1	$	3	$	8	$	12		$	2	$	6	$	14	$	22
Ameren Illinois
	Derivative liabilities – commodity contracts^(a):
	Natural gas	$	—	$	7	$	3	$	10		$	—	$	10	$	4	$	14
	Power	—		—		184		184			—		—		183		183
	Total Ameren Illinois	$	—	$	7	$	187	$	194		$	—	$	10	$	187	$	197



		September 30, 2019								December 31, 2018
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Ameren Missouri
	Derivative liabilities – commodity contracts^(a):
	Fuel oils	$	4	$	—	$	8	$	12	$	2	$	—	$	11	$	13
	Natural gas	—		3		1		4		—		5		—		5
	Power	—		1		3		4		—		1		3		4
	Total Ameren Missouri	$	4	$	4	$	12	$	20	$	2	$	6	$	14	$	22
Ameren Illinois
	Derivative liabilities – commodity contracts^(a):
	Natural gas	$	2	$	14	$	3	$	19	$	—	$	10	$	4	$	14
	Power	—		—		204		204		—		—		183		183
	Total Ameren Illinois	$	2	$	14	$	207	$	223	$	—	$	10	$	187	$	197


(a)	The derivative asset and liability balances are presented net of registrant and counterparty credit considerations.


(b)	Balance excludes $6$8 million and $5 million of cash and cash equivalents, receivables, payables, and accrued income, net, for ~~March 31,~~September 30, 2019, and December 31, 2018, respectively.

Level 3 fuel oils and natural gas derivative contract assets and liabilities measured at fair value on a recurring basis were immaterial for all periods presented. The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:



	2019									2018
	Ameren Missouri			Ameren Illinois			Ameren			Ameren Missouri			Ameren Illinois			Ameren
For the three months ended September 30:
Beginning balance at July 1	$	15		$	(191	)	$	(176	)	$	5		$	(190	)	$	(185	)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities	(4		)	(17		)	(21		)	(4		)	—			(4		)
Purchases	—			—			—			1			—			1
Settlements	(1		)	4			3			(1		)	3			2
Transfers out of Level 3	(2		)	—			(2		)	(1		)	—			(1		)
Ending balance at September 30	$	8		$	(204	)	$	(196	)	$	—		$	(187	)	$	(187	)
Change in unrealized gains/(losses) related to assets/liabilities held at September 30	$	(4	)	$	(17	)	$	(21	)	$	—		$	—		$	—
For the nine months ended September 30:
Beginning balance at January 1	$	—		$	(183	)	$	(183	)	$	7		$	(195	)	$	(188	)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities	12			(32		)	(20		)	(7		)	(1		)	(8		)
Purchases	—			—			—			5			—			5
Settlements	(2		)	11			9			(4		)	9			5
Transfers out of Level 3	(2		)	—			(2		)	(1		)	—			(1		)
Ending balance at September 30	8			(204		)	(196		)	—			(187		)	(187		)
Change in unrealized gains/(losses) related to assets/liabilities held at September 30	$	8		$	(31	)	$	(23	)	$	(1	)	$	(2	)	$	(3	)

2019 2018

Ameren
Missouri
Ameren
Illinois
Ameren Ameren Missouri Ameren Illinois Ameren
Beginning balance at January 1 $ —
$ (183 ) $ (183 ) $ 7
$ (195 ) $ (188 )
Realized and unrealized losses included in regulatory assets/liabilities —
(4 ) (4 ) (2 ) 1
(1 )
Settlements —
3
3
(1 ) 3
2
Ending balance at March 31 $ —
$ (184 ) $ (184 ) $ 4
$ (191 ) $ (187 )
Change in unrealized losses related to assets/liabilities held at March 31 $ —
$ (4 ) $ (4 ) $ (1 ) $ 1
$ —

For the three and nine months ended ~~March 31,~~September 30, 2019 and 2018, there were no material transfers between ~~Level 1 and Level 2, Level 1 and Level 3, or Level 2 and Level 3 related to derivative commodity contracts.~~fair value hierarchy levels.

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

The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of ~~March 31,~~September 30, 2019, and December 31, 2018:

Fair Value^(a)

Weighted Average

Fair Value^(a)

Weighted Average

Commodity

Assets

Liabilities

Valuation Technique(s)

Unobservable Input

Range

Commodity

Assets

Liabilities

Valuation Technique(s)

Unobservable Input

Range

2019

Power^(b)

(186)

Discounted cash flow

Average forward peak and off-peak pricing – forwards/swaps ($/MWh)^(c)

24 – 38

Power^(b)

(207)

Discounted cash flow

Average forward peak and off-peak pricing – forwards/swaps ($/MWh)^(c)

22 – 37

Nodal basis ($/MWh)^(c)

(9) – 0

(2)

Nodal basis ($/MWh)^(c)

(7) – 0

(3)

Fundamental energy production model

Estimated future natural gas prices ($/mmbtu)^(c)

3 – 4

Fundamental energy production model

Estimated future natural gas prices ($/mmbtu)^(c)

3 – 3

2018

Power^(b)

(186)

Discounted cash flow

Average forward peak and off-peak pricing – forwards/swaps ($/MWh)^(c)

23 – 39

Power^(d)

(186)

Discounted cash flow

Average forward peak and off-peak pricing – forwards/swaps ($/MWh)^(c)

23 – 39

Nodal basis ($/MWh)^(c)

(9) – 0

(2)

Nodal basis ($/MWh)^(c)

(9) – 0

(2)

Fundamental energy production model

Estimated future natural gas prices ($/mmbtu)^(c)

3 – 4

Fundamental energy production model

Estimated future natural gas prices ($/mmbtu)^(c)

3 – 4


(a)	The derivative asset and liability balances are presented net of registrant and counterparty credit considerations.


(b)	Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through ~~2022.~~2024. Valuations beyond ~~2022~~2024 use fundamentally modeled pricing by month for peak and off-peak demand.


(c)	Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement.


(d)	Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2022. Valuations beyond 2022 use fundamentally modeled pricing by month for peak and off-peak demand.

The following table sets forth, by level within the fair value hierarchy, the carrying amount and fair value of financial assets and liabilities disclosed, but not carried, at fair value as of ~~March 31,~~September 30, 2019, and December 31, 2018:


	March 31, 2019												September 30, 2019
	Carrying Amount			Fair Value									Carrying Amount			Fair Value
	Carrying Amount			Level 1		Level 2		Level 3			Total		Carrying Amount			Level 1		Level 2		Level 3			Total
Ameren:
Cash, cash equivalents, and restricted cash	$	118		$	118	$	—	$	—		$	118	$	155		$	155	$	—	$	—		$	155
Investments in held-to-maturity debt securities^(a)	270			—		270		—			270
Investments in industrial development revenue bonds^(a)													270			—		270		—			270
Short-term debt	799			—		799		—			799		544			—		544		—			544
Long-term debt (including current portion)^(a)	8,557		^(b)	—		8,623		447		^(c)	9,070		8,987		^(b)	—		9,727		491		^(c)	10,218
Ameren Missouri:
Cash, cash equivalents, and restricted cash	$	12		$	12	$	—	$	—		$	12	$	14		$	14	$	—	$	—		$	14
Investments in held-to-maturity debt securities^(a)	270			—		270		—			270
Investments in industrial development revenue bonds^(a)													270			—		270		—			270
Short-term debt	55			—		55		—			55		144			—		144		—			144
Long-term debt (including current portion)^(a)	4,116		^(b)	—		4,404		—			4,404		4,115		^(b)	—		4,766		—			4,766
Ameren Illinois:
Cash, cash equivalents, and restricted cash	$	93		$	93	$	—	$	—		$	93	$	117		$	117	$	—	$	—		$	117
Short-term debt	126			—		126		—			126		310			—		310		—			310
Long-term debt (including current portion)	3,296		^(b)	—		3,515		—			3,515		3,279		^(b)	—		3,788		—			3,788
	December 31, 2018												December 31, 2018
Ameren:
Cash, cash equivalents, and restricted cash	$	107		$	107	$	—	$	—		$	107	$	107		$	107	$	—	$	—		$	107
Investments in held-to-maturity debt securities^(a)	270			—		270		—			270
Investments in industrial development revenue bonds^(a)													270			—		270		—			270
Short-term debt	597			—		597		—			597		597			—		597		—			597
Long-term debt (including current portion)^(a)	8,439		^(b)	—		8,240		429		^(c)	8,669		8,439		^(b)	—		8,240		429		^(c)	8,669
Ameren Missouri:
Cash, cash equivalents, and restricted cash	$	8		$	8	$	—	$	—		$	8	$	8		$	8	$	—	$	—		$	8
Investments in held-to-maturity debt securities^(a)	270			—		270		—			270
Investments in industrial development revenue bonds^(a)													270			—		270		—			270
Short-term debt	55			—		55		—			55		55			—		55		—			55
Long-term debt (including current portion)^(a)	3,998		^(b)	—		4,156		—			4,156		3,998		^(b)	—		4,156		—			4,156
Ameren Illinois:
Cash, cash equivalents, and restricted cash	$	80		$	80	$	—	$	—		$	80	$	80		$	80	$	—	$	—		$	80
Short-term debt	72			—		72		—			72		72			—		72		—			72
Long-term debt (including current portion)	3,296		^(b)	—		3,391		—			3,391		3,296		^(b)	—		3,391		—			3,391

(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,~~September 30, 2019, and December 31, 2018, the carrying amount of both the investments in industrial development revenue bonds and the finance obligations approximated fair value.

(b)

~~Included~~Includes unamortized debt issuance costs, which were excluded from the fair value measurement, of ~~$62~~$65 million, ~~$25~~$27 million, and ~~$32~~$31 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of ~~March 31,~~September 30, 2019. ~~Included~~Includes unamortized debt issuance costs, which were excluded from the fair value measurement, of $58 million, $22 million, and $31 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2018.


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

NOTE 8 – RELATED-PARTY TRANSACTIONS

In the normal course of business, Ameren Missouri and Ameren Illinois have engaged in, and may in the future engage in, affiliate transactions. These transactions primarily consist of natural gas and power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between Ameren’s subsidiaries are reported as affiliate transactions on their individual financial statements, but those transactions are eliminated in consolidation for Ameren’s consolidated financial statements. For a discussion of material related-party agreements and money pool arrangements, see Note 13 – Related-party Transactions and Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of the Form 10-K.

Electric Power Supply Agreement

In April and September 2019, Ameren Illinois conducted a procurement ~~event,~~events, administered by the IPA, to purchase energy products. Ameren Missouri was among the winning suppliers in ~~this event.~~these events. As a result, in April 2019, Ameren Missouri and Ameren Illinois entered into an energy product agreement by which Ameren Missouri agreed to sell, and Ameren Illinois agreed to purchase, 288,000 megawatthours at an average price of $35 per megawatthour during the period of January 2020 through December 2021. In September 2019, Ameren Missouri and Ameren Illinois entered into an energy product agreement by which Ameren Missouri agreed to sell, and Ameren Illinois agreed to purchase, 170,800 megawatthours at an average price of $29 per megawatthour during the period of April 2020 through November 2021.

Software Licensing Agreement

In September 2019, Ameren Missouri purchased a license for advanced metering infrastructure software from Ameren Illinois. The amount of the $24 million cost-based transaction price over the $5 million remaining carrying value of the software was recorded as revenue by Ameren Illinois, with $14 million of revenue recorded at Ameren Illinois Electric Distribution and $5 million recorded at Ameren Illinois Natural Gas. The revenue recorded at Ameren Illinois Electric Distribution was reflected in formula ratemaking, which resulted in no impact to net income. Per authoritative accounting guidance for sales to rate-regulated entities, the revenue recognized by Ameren Illinois was not eliminated upon consolidation by Ameren. Ameren Missouri's $24 million software investment is included in "Property, Plant, and Equipment, Net.” Ameren Missouri and Ameren Illinois included $24 million in "Accounts payable – affiliates" and "Accounts receivable – affiliates," respectively, as of September 30, 2019, as a result of this transaction.

Tax Allocation Agreement

See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for a discussion of the tax allocation agreement. The following table presents the ~~impact~~affiliate balances related to income taxes for Ameren Missouri and Ameren Illinois as of September 30, 2019, and December 31, 2018:



	September 30, 2019				December 31, 2018
	Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois
Income taxes payable to parent^(a)	$	58	$	24	$	16	$	7
Income taxes receivable from parent^(b)	—		—		—		6


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


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

Effects of Related-party Transactions on the Statement of Income

The following table presents the effect on Ameren Missouri and Ameren Illinois of related-party transactions for the three and nine months ended ~~March 31,~~September 30, 2019 and ~~2018~~:2018:

Three Months
Agreement
Income Statement
Line Item

Ameren
Missouri

Ameren
Illinois
Ameren Missouri power supply Operating Revenues 2019 $ (b)
$ (a)
agreements with Ameren Illinois 2018 3
(a)
Ameren Missouri and Ameren Illinois Operating Revenues 2019 7
1
rent and facility services 2018 5
1
Ameren Missouri and Ameren Illinois Operating Revenues 2019 (b)
(b)
miscellaneous support services 2018 (b)
(b)
Total Operating Revenues 2019 $ 7
$ 1
2018 8
1
Ameren Illinois power supply Purchased Power 2019 $ (a)
$ (b)
agreements with Ameren Missouri 2018 (a)
3
Ameren Illinois transmission Purchased Power 2019 (a)
(b)
services with ATXI 2018 (a)
(b)
Total Purchased Power 2019 $ (a)
$ (b)
2018 (a)
3
Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2019 $ (b)
$ 1
rent and facility services 2018 (b)
2
Ameren Services support services Other Operations and Maintenance 2019 32
30
agreement 2018 33
30
Total Other Operations and Maintenance 2019 $ 32
$ 31
2018 33
32
Money pool borrowings (advances) Interest Charges/ Other Income, Net 2019 $ —
$ —
2018 (b)
(b)



				Three Months				Nine Months
Agreement	Income Statement Line Item			Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois
Ameren Missouri power supply	Operating Revenues	2019	$	1	$	(a)	$	3	$	(a)
agreements with Ameren Illinois		2018		5		(a)		11		(a)
Ameren Missouri and Ameren Illinois	Operating Revenues	2019	$	7	$	1	$	20	$	2
rent and facility services		2018		6		(b)		17		2
Ameren Missouri and Ameren Illinois	Operating Revenues	2019	$	1	$	(b)	$	1	$	1
miscellaneous support services		2018		(b)		(b)		(b)		(b)



				Three Months				Nine Months
Agreement	Income Statement Line Item			Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois
Ameren Missouri software licensing	Operating Revenues	2019	$	(a)	$	19	$	(a)	$	19
with Ameren Illinois		2018		(a)		(a)		(a)		(a)
Total Operating Revenues		2019	$	9	$	20	$	24	$	22
		2018		11		(b)		28		2
Ameren Illinois power supply	Purchased Power	2019	$	(a)	$	1	$	(a)	$	3
agreements with Ameren Missouri		2018		(a)		5		(a)		11
Ameren Illinois transmission	Purchased Power	2019	$	(a)	$	1	$	(a)	$	1
services with ATXI		2018		(a)		(b)		(a)		1
Total Purchased Power		2019	$	(a)	$	2	$	(a)	$	4
		2018		(a)		5		(a)		12
Ameren Missouri and Ameren Illinois	Other Operations and Maintenance	2019	$	(b)	$	1	$	1	$	4
rent and facility services		2018		1		1		2		4
Ameren Services support services	Other Operations and Maintenance	2019	$	34	$	30	$	98	$	91
agreement		2018		36		33		101		93
Total Other Operations and		2019	$	34	$	31	$	99	$	95
Maintenance		2018		37		34		103		97
Money pool borrowings (advances)	Interest Charges/Other Income, Net	2019	$	(b)	$	(b)	$	(b)	$	(b)
		2018		(b)		(b)		(b)		(b)


(a)	Not applicable.


(b)	Amount less than $1 million.

NOTE 9 – COMMITMENTS AND CONTINGENCIES

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

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

Other Obligations

To supply a portion of the fuel requirements of Ameren Missouri’s energy centers, Ameren Missouri has entered into various long-term commitments for the procurement of coal, natural gas, nuclear fuel, and methane gas. Ameren Missouri and Ameren Illinois also have entered into various long-term commitments for purchased power and natural gas for distribution. The table below presents our estimated minimum fuel, purchased power, and other commitments at ~~March 31,~~September 30, 2019. Ameren’s and Ameren Illinois’ purchased power commitments include the Ameren Illinois 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, among other agreements, at ~~March 31,~~September 30, 2019.


	Coal		Natural Gas^(a)		Nuclear Fuel		Purchased Power^(b)(c)			Methane Gas		Other		Total		Coal		Natural Gas^(a)		Nuclear Fuel		Purchased Power^(b)(c)			Methane Gas		Other		Total
Ameren:
2019	$	279	$	154	$	25	$	88	^(d)	$	2	$	52	$	600	$	142	$	51	$	21	$	56	^(d)	$	1	$	20	$	291
2020	160		158		43		54			3		42		460		226		172		43		146		^(d)	3		40		630
2021	121		85		58		10			3		30		307		195		105		59		50			3		26		438
2022	72		32		13		—			3		26		146		137		49		12		12			3		22		235
2023	—		8		41		—			3		29		81		46		25		42		2			3		22		140
Thereafter	—		34		29		—			27		71		161		—		48		29		—			26		85		188
Total	$	632	$	471	$	209	$	152		$	41	$	250	$	1,755	$	746	$	450	$	206	$	266		$	39	$	215	$	1,922
Ameren Missouri:
2019	$	279	$	33	$	25	$	—		$	2	$	39	$	378	$	142	$	10	$	21	$	—		$	1	$	16	$	190
2020	160		34		43		—			3		29		269		226		39		43		—			3		29		340
2021	121		16		58		—			3		25		223		195		23		59		—			3		22		302
2022	72		5		13		—			3		26		119		137		11		12		—			3		22		185
2023	—		5		41		—			3		29		78		46		10		42		—			3		22		123
Thereafter	—		13		29		—			27		55		124		—		17		29		—			26		48		120
Total	$	632	$	106	$	209	$	—		$	41	$	203	$	1,191	$	746	$	110	$	206	$	—		$	39	$	159	$	1,260
Ameren Illinois:
2019	$	—	$	121	$	—	$	88	^(d)	$	—	$	5	$	214	$	—	$	41	$	—	$	56	^(d)	$	—	$	2	$	99
2020	—		124		—		54			—		4		182		—		133		—		146		^(d)	—		1		280
2021	—		69		—		10			—		—		79		—		82		—		50			—		—		132
2022	—		27		—		—			—		—		27		—		38		—		12			—		—		50
2023	—		3		—		—			—		—		3		—		15		—		2			—		—		17
Thereafter	—		21		—		—			—		—		21		—		31		—		—			—		—		31
Total	$	—	$	365	$	—	$	152		$	—	$	9	$	526	$	—	$	340	$	—	$	266		$	—	$	3	$	609


(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 ~~2034~~2035 with various renewable energy suppliers due to the contingent nature of the payment ~~amounts.~~amounts, with the exception of expected payments of $11 million through 2023.


(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 10-year agreements to acquire zero emission credits. 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 ~~$10~~$44 million of zero emission credits through May ~~2019.~~2020.

In April 2019, Ameren Illinois conducted procurement events, administered by the IPA, to purchase energy products through May 2022. In the April 2019 procurement event, Ameren Illinois contracted to purchase 3,704,000 megawatthours of energy products for $108 million from June 2019 through May 2022. See Note 8 – Related-party Transactions for additional information regarding energy product agreements between Ameren Missouri and Ameren Illinois as a result of the April procurement event.

Environmental Matters

We are subject to various environmental laws, including statutes and regulations, enforced by federal, state, and local authorities. The development and operation of electric generation, transmission, and distribution facilities and natural gas storage, transmission, and distribution facilities can trigger compliance obligations with respect to environmental laws. These laws address emissions, discharges to water, water intake, impacts to air, land, and water, and chemical and waste handling. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing or modified facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures.

The EPA has promulgated environmental regulations that have a significant impact on the electric utility industry. Over time, compliance with these regulations could be costly for Ameren Missouri, which operates coal-fired power plants.As of December 31, 2018, Ameren Missouri’s fossil fuel-fired energy centers represented 16% and 32% of Ameren’s and Ameren Missouri’s rate base, respectively. Regulations that apply to air emissions from the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO₂, particulate matter, NO_x,mercury, toxic metals, and acid gases, and CO₂ emissions from new power plants. Water intake and discharges from power plants are regulated under the Clean Water Act. Such regulation could require modifications to water intake structures or more stringent limitations on wastewater discharges at Ameren Missouri’s energy centers, either of which could result in significant capital expenditures. The management and disposal of coal ash is regulated under the CCR rule, which will require the closure of surface impoundments and the installations of dry ash handling systems at several of Ameren Missouri’s energy centers. The individual or combined effects of existing environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or

alteration of operations at some of Ameren Missouri’s energy centers. Ameren and Ameren Missouri expect that such compliance costs would be recoverable through rates, subject to MoPSC prudence review, but the timing of costs and their recovery could be subject to regulatory lag.

Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $300 million to $400 million from 2019 through 2023 in order to comply with existing environmental regulations. Additional environmental controls beyond 2023 could be required. This estimate of capital expenditures includes expenditures required by the CCR regulations, by the Clean Water Act rule applicable to cooling water intake structures at existing power plants, and by effluent limitation guidelines applicable to steam electric generating units, all of which are discussed below. This estimate does not include capital expenditures that may be required as a result of the NSR and Clean Air litigation discussed below. Ameren Missouri’s current plan for compliance with existing air emission regulations includes burning ultra-low-sulfur coal and installing new or optimizing existing pollution control equipment. The actual amount of capital expenditures required to comply with existing environmental regulations may vary substantially from the above estimate because of uncertainty as to whether the EPA will substantially revise regulatory obligations, exactly which compliance strategies will be used and their ultimate cost, among other things.

The following sections describe the more significant environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. The EPA has initiated an administrative review of several regulations and proposed amendments to regulations and guidelines, including to the effluent limitation guidelines and the CCR Rule, which could ultimately result in the revision of all or part of such rules.

Clean Air Act

Federal and state laws, including CSAPR, regulate emissions of SO₂ and NO_x through ~~emission~~the reduction of emissions at their source ~~reductions~~ and the use and retirement of emission allowances. The first phase of the CSAPR emission reduction requirements became effective in 2015. The second phase of emission reduction requirements, which were revised by the EPA in 2016, became effective in 2017; additional emission reduction requirements may apply in subsequent years. To achieve compliance with the CSAPR, Ameren Missouri burns ultra-low-sulfur coal, operates ~~two~~2 scrubbers at its Sioux energy center, and optimizes other existing pollution control equipment. Ameren Missouri expects to incur additional costs to lower its emissions at one or more of its energy centers to comply with the CSAPR in future years. These higher costs are expected to be recovered from customers through the FAC or higher base rates.

CO₂ Emissions Standards

In 2015, the EPA issued the Clean Power Plan, which would have established CO₂ emissions standards applicable to existing power plants. The United States Supreme Court stayed the rule in February ~~2016, pending various legal challenges.~~2016. In ~~August 2018,~~July 2019, the EPA ~~proposed to repeal and replace~~finalized regulations that repealed the Clean Power Plan and replaced it with ~~a proposed new rule known as~~ the Affordable Clean Energy Rule, which establishes emission guidelines for states to follow in developing plans to limit CO₂ emissions from ~~power plants.~~coal-fired electric generating units. The EPA ~~proposes to use~~has identified certain efficiency measures as the best system of emission reduction for coal-fired ~~power plants.~~electric generating units. The Affordable Clean Energy Rule went into effect on September 6, 2019. The rule requires the state of Missouri to develop a compliance plan and submit it to the EPA for approval by September 2022. The plan is expected to ~~finalize~~include a standard of performance for each affected generating unit. We are evaluating the impact of the adoption and implementation of the Affordable Clean Energy ~~rule in~~Rule and, along with other stakeholders, will be working with the ~~first half~~state of ~~2019. We~~Missouri to develop the compliance plan submitted to the EPA. At this time, we cannot predict the outcome of ~~EPA’s rulemaking or~~Missouri’s compliance plan development process. As such, the impact on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri is uncertain. We also cannot predict the outcome of any potential legal challenges ~~related~~ to ~~such rulemaking.~~the rule.

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 complaint, as amended in October 2013, alleged~~Missouri alleging 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. ~~The litigation has been divided into two phases: liability and remedy.~~ In ~~the first phase, in~~ January 2017, the district court issued a liability ruling and in September 2019 entered a final judgment that ordered Ameren Missouri to install a flue gas desulfurization system at the ~~projects violated provisions of~~Rush Island energy center and a dry sorbent injection system at the ~~Clean Air Act and~~Labadie energy center. There were no fines in the order. In October 2019, Ameren Missouri ~~law. In the second phase,~~appealed the district court will determine the actions required to remedy the violations found in the liability phase. The EPA previously withdrew all claims for penalties and fines. A trial on the scope of the appropriate remedy occurred in April 2019, and a final ruling from the court is expected by the end of 2019. Once the court issues its final order and judgment, Ameren Missouri will seek a stay of that order while it seeks an appeal of the liabilitycourt’s ruling to the United States Court of Appeals for the Eighth Circuit. Additionally, in October 2019, following a request by Ameren Missouri, the district court stayed the majority of its order while the case is appealed. Ameren Missouri believes that the district court both misinterpreted and misapplied the law in its ruling. We are unable to predict the ultimate resolution of this matter. Based on the initial procedural schedule, the Court of Appeals for the Eighth Circuit is expected to hear oral arguments in 2020; however, it is under no deadline to issue a ruling in this case.

The ultimate resolution of this matter could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. Among other things and subject to economic and regulatory considerations, resolution of this matter could result in increased capital expenditures for the installation of pollution control equipment, as well as increased operations and maintenance expenses. WeCapital expenditures to comply with the district court’s order for installation of a flue gas desulfurization system at the Rush Island energy center are ~~unable~~estimated at approximately $1 billion. Further, the flue gas desulfurization system would result in additional operation and maintenance expenses of $30 million to ~~predict~~$50 million annually for the ~~ultimate resolution~~life of ~~this matter~~the energy center. Estimates for the additional capital expenditures and operation and maintenance expenses for the Labadie energy center to comply with the district court’s order are under development. As a

result of the district court’s stay, Ameren Missouri does not expect to make significant capital expenditures or incur operations and maintenance expenses related to the ~~costs that might be incurred.~~district court’s order while the case is under appeal.

Clean Water Act

In July 2018, the United States Court of Appeals for the Second Circuit upheld the EPA’s Section 316(b) Rule applicable to cooling water intake structures at existing power plants. The rule requires a case-by-case evaluation and plan for reducing the number of aquatic organisms impinged on a power plant’s cooling water intake screens or entrained through the plant’s cooling water system. All of Ameren Missouri’s coal-fired and

nuclear energy centers are subject to the cooling water intake structures rule. ~~The~~Requirements of the rule ~~will be~~are being implemented by Ameren Missouri during the permit renewal process of each energy center’s water discharge permit, which is expected to be completed by 2023.

In 2015, the EPA issued a rule to revise the effluent limitation guidelines applicable to steam electric generating units. These guidelines established national standards for water discharges that are based on the effectiveness of available control technology. The EPA’s 2015 rule prohibits effluent discharges of certain waste streams and imposes more stringent limitations on certain water discharges from power plants. In September 2017, the EPA published a rule that postponed the compliance dates by two years for the limitations applicable to ~~two~~2 specific waste streams so that it could potentially revise those standards. To meet the requirements of the guidelines, Ameren Missouri is ~~in the process of~~ constructing wastewater treatment facilities ~~that meet the limitations in these guidelines~~and dry ash handling systems at ~~three~~3 of its energy ~~centers.~~centers and is scheduled to complete the projects in 2020. Estimated capital expenditures to complete these projects are included in the CCR management compliance plan, discussed below.

CCR Management

In 2015, the EPA issued the CCR rule, which established ~~regulations regarding~~requirements for the management and disposal of CCR from coal-fired ~~energy centers.~~power plants. These regulations affect CCR disposal and handling costs at Ameren Missouri’s energy centers. Ameren Missouri is in the process of closing its surface impoundments, ~~and anticipates~~with the last of such ~~CCR storage facilities to be closed by~~closures scheduled for 2023. In July 2018, the EPA issued revisions to the CCR rule, proposed additional revisions, and indicated that additional revisions to the CCR rule are likely. Ameren and Ameren Missouri have AROs of ~~$131~~$160 million recorded on their respective balance sheets as of ~~March 31,~~September 30, 2019, associated with CCR storage ~~facilities that reflect the regulations issued in 2015.~~facilities. Ameren Missouri estimates it will need to make capital expenditures of $150 million to $200 million from 2019 through 2023 to implement its CCR management compliance plan, which includes installation of dry ash handling systems, ~~waste water~~wastewater treatment facilities, and groundwater monitoring equipment.

Remediation

The Ameren Companies are involved in a number of remediation actions to clean up sites impacted by the use or disposal of materials containing hazardous substances. Federal and state laws can require responsible parties to fund remediation regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site. Ameren Missouri and Ameren Illinois have each been identified ~~by federal or state governments~~ as a potentially responsible party at several contaminated sites.

As of ~~March 31,~~September 30, 2019, Ameren Illinois has remediated the majority of the 44 former MGP sites in Illinois it owned or for which it was otherwise responsible. Ameren Illinois estimates it could substantially conclude remediation efforts at ~~its~~the remaining sites by 2023. The ICC allows Ameren Illinois to recover such remediation and related litigation costs from its electric and natural gas utility customers through environmental cost riders. Costs are subject to annual prudence review by the ICC. As of ~~March 31,~~September 30, 2019, Ameren Illinois estimated the remaining obligation related to these former MGP sites at ~~$145~~$139 million to ~~$215~~$209 million. Ameren and Ameren Illinois recorded a liability of ~~$145~~$139 million to represent the estimated minimum obligation for these sites, as no other amount within the range was a better estimate.

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

Our operations or those of our predecessor companies involve the use of, disposal of, and, in appropriate circumstances, the cleanup of substances regulated under environmental laws. We are unable to determine whether such practices will result in future environmental commitments or will affect our results of operations, financial position, or liquidity.

NOTE 10 – CALLAWAY ENERGY CENTER

~~Decommissioning~~

~~Electric rates charged to customers provide~~See Note 9 – Callaway Energy Center under Part II, Item 8, of the Form 10-K for ~~the~~information regarding spent nuclear fuel recovery, recovery of ~~the Callaway energy center’s~~ decommissioning costs, ~~which include decontamination, dismantling,~~ and ~~site restoration costs, over~~ the ~~expected life of the nuclear energy center. Amounts collected from customers are deposited into the external~~ nuclear decommissioning trust fund to provide for the Callaway energy center’s decommissioning. It is assumed that the Callaway energy center site will be decommissioned 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. Annual decommissioning costs of $7 million are included in the costs used to establish electric rates for Ameren Missouri’s customers.

fund. The fair value of the trust fund for Ameren Missouri’s Callaway energy center is reported as “Nuclear decommissioning trust fund” in Ameren’s and Ameren Missouri’s balance sheets. This amount is legally restricted and may be used only to fund the costs of nuclear decommissioning. Changes in the fair value of the trust fund are

recorded as an increase or decrease to the nuclear decommissioning trust

fund, with an offsetting adjustment to the related regulatory liability. ~~If the assumed return on trust assets is not earned, Ameren Missouri believes that it is probable that any such earnings deficiency will be recovered in rates.~~

Insurance

The following table presents insurance coverage at Ameren Missouri’s Callaway energy center as of ~~April 1,~~September 30, 2019. The property coverage and the nuclear liability coverage renewal dates are April 1 and January 1, respectively, of each year. Both coverages were renewed in 2019.


Type and Source of Coverage	Maximum Coverages			Maximum Assessments for Single Incidents			Maximum Coverages			Maximum Assessments for Single Incidents
Public liability and nuclear worker liability:
American Nuclear Insurers	$	450		$	—		$	450		$	—
Pool participation	13,623		^(a)	138		^(b)	13,486		^(a)	138		^(b)
	$	14,073	^(c)	$	138		$	13,936	^(c)	$	138
Property damage:
NEIL and EMANI	$	3,200	^(d)	$	28	^(e)	$	3,200	^(d)	$	28	^(e)
Replacement power:
NEIL	$	490	^(f)	$	7	^(e)	$	490	^(f)	$	7	^(e)


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


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


(c)	Limit of liability for each incident 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 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 twelve weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter for a total not exceeding the policy limit of $490 million. Nonradiation events are limited to $328 million.

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

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

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

NOTE 11 – RETIREMENT BENEFITS

The following table presents the components of the net periodic benefit cost (income) incurred for Ameren’s pension and postretirement benefit plans for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Pension Benefits						Postretirement Benefits						Pension Benefits												Postretirement Benefits
	Three Months						Three Months						Three Months						Nine Months						Three Months						Nine Months
	2019			2018			2019			2018			2019			2018			2019			2018			2019			2018			2019			2018
Service cost^(a)	$	22		$	25		$	4		$	5		$	22		$	25		$	66		$	75		$	4		$	6		$	13		$	16
Non-service cost components:
Interest cost	47			42			11			11			46			42			139			126			11			10			32			30
Expected return on plan assets	(69		)	(69		)	(19		)	(19		)	(69		)	(68		)	(207		)	(206		)	(19		)	(20		)	(57		)	(58		)
Amortization of:
Prior service benefit	—			—			(1		)	(1		)	—			—			—			—			(1		)	(1		)	(4		)	(3		)
Actuarial loss (gain)	6			16			(4		)	—			6			17			19			51			(4		)	(2		)	(11		)	(5		)
Total non-service cost components^(b)	$	(16	)	$	(11	)	$	(13	)	$	(9	)	$	(17	)	$	(9	)	$	(49	)	$	(29	)	$	(13	)	$	(13	)	$	(40	)	$	(36	)
Net periodic benefit cost (income)	$	6		$	14		$	(9	)	$	(4	)	$	5		$	16		$	17		$	46		$	(9	)	$	(7	)	$	(27	)	$	(20	)


(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.

Ameren Missouri and Ameren Illinois are responsible for their respective shares of Ameren’s pension and postretirement costs. The following table presents the respective share of net periodic pension and other postretirement benefit costs (income) incurred for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:



	Pension Benefits												Postretirement Benefits
	Three Months						Nine Months						Three Months						Nine Months
	2019			2018			2019			2018			2019			2018			2019			2018
Ameren Missouri^(a)	$	1		$	6		$	3		$	17		$	(1	)	$	(1	)	$	(4	)	$	(1	)
Ameren Illinois	5			11			15			30			(8		)	(6		)	(23		)	(19		)
Other	(1		)	(1		)	(1		)	(1		)	—			—			—			—
Ameren^(a)	$	5		$	16		$	17		$	46		$	(9	)	$	(7	)	$	(27	)	$	(20	)

Pension Benefits Postretirement Benefits
Three Months Three Months
2019 2018 2019 2018
Ameren Missouri^(a)
$ 1
$ 5
$ (2 ) $ —
Ameren Illinois 5
9
(7 ) (4 )
Ameren^(a)
$ 6
$ 14
$ (9 ) $ (4 )


(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.

NOTE 12 – INCOME TAXES

The following table presents a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:



	Ameren			Ameren Missouri			Ameren Illinois
	2019	2018		2019	2018		2019	2018
Three Months
Federal statutory corporate income tax rate:	21%	21%		21%	21%		21%	21%
Increases (decreases) from:
Amortization of excess deferred taxes	(7)	(6)	^(a)	(11)	(7)	^(a)	(3)	(3)
Depreciation differences	—	—		—	—		—	(1)
Amortization of deferred investment tax credit	(1)	(1)		(1)	—		—	—
State tax	6	6		5	4		6	5
Stock-based compensation	1	—		—	—		—	—
TCJA	—	3	^(b)	—	—		—	4	^(b)
Effective income tax rate	20%	23%		14%	18%		24%	26%

Ameren Ameren Missouri Ameren Illinois
Three Months 2019 2018 2019 2018 2019 2018
Federal statutory corporate income tax rate: 21% 21% 21% 21% 21% 21%
Increases (decreases) from:
Amortization of excess deferred taxes (7) (2)
^(a)
(12) —
^(a)
(3) (3)
Other depreciation differences — — — 1 — —
Amortization of deferred investment tax credit (1) (1) (1) (1) — —
State tax 6 7 4 4 7 7
Stock-based compensation (7) (3) — — — —
Other — — (3) — — —
Effective income tax rate 12% 22% 9% 25% 25% 25%



	Ameren			Ameren Missouri			Ameren Illinois
	2019	2018		2019	2018		2019	2018
Nine Months
Federal statutory corporate income tax rate:	21%	21%		21%	21%		21%	21%
Increases (decreases) from:
Amortization of excess deferred taxes	(7)	(3)	^(a)	(12)	(4)	^(a)	(4)	(4)
Amortization of deferred investment tax credit	(1)	(1)		(1)	—		—	—
State tax	6	6		5	4		7	7
Stock-based compensation	(1)	—		—	—		—	—
TCJA	—	1	^(b)	—	—		—	1	^(b)
Other	—	(1)		—	—		—	—
Effective income tax rate	18%	23%		13%	21%		24%	25%


(a)	Based on an order by the MoPSC in July 2018, Ameren Missouri began amortizing excess deferred taxes in August 2018.


(b)	The Ameren Companies updated their respective provisional estimates recorded related to TCJA, as discussed below.

Federal Tax Reform

As of December 31, 2017, the Ameren Companies made provisional estimates for the measurement and accounting of certain effects of the TCJA in accordance with SEC guidance, which provides for a one-year period in which to complete the required analysis and update provisional estimates. During the three and nine months ended September 30, 2018, Ameren, Ameren Missouri, and Ameren Illinois updated their respective provisional estimates and recorded $13 million, $4 million, and $4 million, respectively, of income tax expense, primarily due to the application of proposed IRS regulations on depreciation transition rules. As of December 31, 2018, Ameren, Ameren Missouri, and Ameren Illinois completed their accounting for certain effects of the TCJA.

NOTE 13 – SUPPLEMENTAL INFORMATION

Cash, Cash Equivalents, and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets and the statements of cash flows as of ~~March 31,~~September 30, 2019, and December 31, 2018:



	September 30, 2019						December 31, 2018
	Ameren		Ameren Missouri		Ameren Illinois		Ameren		Ameren Missouri		Ameren Illinois
Cash and cash equivalents	$	20	$	—	$	—	$	16	$	—	$	—
Restricted cash included in “Other current assets”	14		4		6		13		4		6
Restricted cash included in “Other assets”	111		—		111		74		—		74
Restricted cash included in “Nuclear decommissioning trust fund”	10		10		—		4		4		—
Total cash, cash equivalents, and restricted cash	$	155	$	14	$	117	$	107	$	8	$	80

March 31, 2019 December 31, 2018
Ameren Ameren
Missouri Ameren
Illinois Ameren Ameren
Missouri Ameren
Illinois
Cash and cash equivalents $ 8
$ —
$ —
$ 16
$ —
$ —
Restricted cash included in “Other current assets” 16
5
6
13
4
6
Restricted cash included in “Other assets” 87
—
87
74
—
74
Restricted cash included in “Nuclear decommissioning trust fund” 7
7
—
4
4
—
Total cash, cash equivalents, and restricted cash $ 118
$ 12
$ 93
$ 107
$ 8
$ 80

Restricted cash included in “Other current assets” primarily represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees. Restricted cash included in “Other assets” on Ameren’s and Ameren Illinois’ balance sheets primarily represents amounts collected under a cost recovery rider restricted for use in the procurement of renewable energy credits and amounts in a trust fund restricted for the use of funding certain asbestos-related claims.

Accounts Receivable

“Accounts receivable – trade” on Ameren’s and Ameren Illinois’ balance sheets include certain receivables purchased at a discount from alternative retail electric suppliers that elect to participate in the utility consolidated billing program. At ~~March 31,~~September 30, 2019, and December 31, 2018, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of ~~$38~~$37 million and $33 million, respectively.

For the three and nine months ended~~March 31,~~ September 30, 2019 and 2018, the Ameren Companies recorded immaterial bad debt expense.

Leases

In the first quarter of 2019, we adopted authoritative accounting guidance related to leases, which affected our financial position, but did not materially affect our results of operations or liquidity. The most significant impact for us was the recognition of right-of-use assets and lease liabilities for operating leases, while the accounting for our finance leases remained substantially unchanged. Ameren and Ameren Missouri recognized right-of-use assets and offsetting lease liabilities of $38 million and $36 million at January 1, 2019, respectively, primarily

related to rail car leases. The effect of the adoption was immaterial at Ameren Illinois. No adjustment to comparative periods was made. We elected the available practical expedients upon adoption.

Ameren Missouri primarily leases rail cars under operating lease arrangements for the transportation of coal inventory to its energy centers. Although Ameren Missouri has options to renew a portion of these arrangements for up to five years on similar terms, the exercise of these options was not assumed in the recognition of right-of-use assets and lease obligations. For rail car leases, we account for the lease and non-lease components as a single lease component.

The operating lease expense and the cash paid for amounts included in the measurement of operating lease liabilities at Ameren and Ameren Missouri were immaterial for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018.

The following table provides supplemental balance sheet information related to operating leases as of ~~March 31,~~September 30, 2019:


	Ameren			Ameren Missouri			Ameren			Ameren Missouri
Other assets	$	36		$	34		$	38		$	36
Other current liabilities	7			6			8			7
Other deferred credits and liabilities	29			28			30			29
Weighted average remaining operating lease term	6 years			6 years			6 years			6 years
Weighted average discount rate^(a)	3.6		%	3.6		%	3.5		%	3.4		%


(a)	As an implicit rate is not readily determinable under most of our lease agreements, ~~do not provide an implicit rate,~~ we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. We use ~~the~~an implicit rate when readily determinable.

The following table presents Ameren’s and Ameren Missouri’s remaining maturities of operating lease liabilities as of ~~March 31,~~September 30, 2019:



	Ameren		Ameren Missouri
2019	$	2	$	2
2020	8		8
2021	8		7
2022	7		6
2023	6		6
Thereafter	11		10
Total lease payments	42		39
Less imputed interest	4		3
Total^(a)	$	38	$	36

Ameren Ameren Missouri
2019 $ 6
$ 5
2020 7
7
2021 7
6
2022 6
5
2023 5
5
Thereafter 10
10
Total lease payments 41
38
Less imputed interest 5
4
Total^(a)
$ 36
$ 34

(a)

The amount of remaining maturities of operating lease liabilities under previous authoritative accounting guidance as of December 31, 2018, is materially consistent towith the amount as of ~~March 31,~~September 30, 2019. Maturities of certain financing arrangements, including the Peno Creek and Audrain energy centers' long-term agreements, are no longer required to be disclosed as lease-related maturities. See Note 5 -– Long-Term Debt and Equity Financings under Part II, Item 8, in the Form 10-K for further information on financing arrangements.

Supplemental Cash Flow Information

The following table provides noncash financing and investing activity excluded from the statements of cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018:



	September 30, 2019								September 30, 2018
	Ameren			Ameren Missouri		Ameren Illinois			Ameren		Ameren Missouri		Ameren Illinois
Investing
Exchange of bond investments for the extinguishment of senior unsecured notes^(a)	$	17		$	—	$	17		$	—	$	—	$	—
Accrued capital expenditures	273			138		128			240		94		133
Net realized and unrealized gain – nuclear decommissioning trust fund	100			100		—			33		33		—
Financing
Exchange of bond investments for the extinguishment of senior unsecured notes^(a)	$	(17	)	$	—	$	(17	)	$	—	$	—	$	—
Issuance of common stock for stock-based compensation	54			—		—			35		—		—


(a)	See Note 4 – Long-term Debt and Equity Financings for additional information.

March 31, 2019 March 31, 2018
Ameren
Ameren
Missouri
Ameren
Illinois
Ameren
Ameren
Missouri
Ameren
Illinois
Accrued capital expenditures $ 208
$ 92
$ 106
$ 202
$ 73
$ 114
Net realized and unrealized gain (loss) – nuclear decommissioning trust fund
64
64
—
(11 ) (11 ) —

Asset Retirement Obligations

The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the ~~three~~nine months ended ~~March 31,~~September 30, 2019:


	Ameren Missouri				Ameren Illinois^(a)			Ameren				Ameren Missouri				Ameren Illinois			Ameren
Balance at December 31, 2018	$	646		^(a)	$	4	^(b)	$	650		^(a)	$	646		^(a)	$	4	^(b)	$	650		^(a)
Liabilities settled	(3		)		—			(3		)		(10		)		—			(10		)
Accretion	6			^(c)	—			6			^(c)	21			^(c)	—			21			^(c)
Balance at March 31, 2019	$	649		^(a)	$	4	^(b)	$	653		^(a)
Change in estimates												33			^(d)	—			33			^(d)
Balance at September 30, 2019												$	690		^(a)	$	4	^(b)	$	694		^(a)


(a)	Balance included $23 million in “Other current liabilities” on the balance sheet as of both December 31, 2018, and ~~March 31,~~September 30, 2019.


(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.


(d)	Ameren Missouri changed its fair value estimate primarily due to an increase in the cost estimate for closure of certain CCR storage facilities.

Stock-based Compensation

The following table summarizes Ameren's nonvested performance share unit and restricted stock unit activity for the ~~three~~nine months ended ~~March 31,~~September 30, 2019:


	Performance Share Units					Restricted Stock Units				Performance Share Units					Restricted Stock Units
	Share Units		Weighted-average Fair Value per Share Unit			Stock Units		Weighted-average Fair Value per Stock Unit		Share Units		Weighted-average Fair Value per Share Unit			Stock Units		Weighted-average Fair Value per Stock Unit
Nonvested at January 1, 2019^(a)	682,811		$	56.58		155,253		$	57.38	682,811		$	56.58		155,253		$	57.38
Granted	288,956		67.42		^(b)	124,925		65.23		297,728		67.42		^(b)	128,883		65.49
Forfeitures	(2,228	)	65.06			(833	)	63.16		(33,195	)	64.34			(11,028	)	62.74
Vested and undistributed^(c)	(65,458	)	62.04			(14,047	)	61.77		(180,823	)	62.24			(40,616	)	61.91
Vested and distributed	(176,923	)	44.13			—		—		(176,923	)	44.13			(2,403	)	54.30
Nonvested at March 31, 2019^(d)	727,158		$	63.40		265,298		$	60.64
Nonvested at September 30, 2019^(d)										589,598		$	63.62		230,089		$	60.90


(a)	Does not include 619,783 ~~vested and undistributed~~ performance share units and 26,557 restricted stock units that were vested and ~~undistributed restricted stock units.~~undistributed.


(b)	Significant inputs to the Monte Carlo simulation model used to calculate the fair value of performance share units granted include Ameren’s closing common share price of $65.23 at December 31, 2018, Ameren’s common stock volatility of 17%, a volatility range for the peer group of 15% to 25%, and a three-year risk-free rate of 2.46%.


(c)	Vested and undistributed units are awards that ~~vested~~vest on a pro-rata basis due to attainment of retirement eligibility by certain employees, but have not yet been distributed. For vested and undistributed performance share units, the number of shares issued for retirement-eligible employees will vary depending on actual performance over the ~~three-year~~three year performance period.


(d)	Does not include ~~333,466 vested and undistributed~~448,831 performance share units and ~~40,604~~67,173 restricted stock units that were vested and ~~undistributed restricted stock units.~~undistributed.

For the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018, excess tax benefits associated with the settlement of stock-based compensation awards reduced income tax expense by $14 million and $6 million, respectively.

Deferred Compensation

As of ~~March 31,~~September 30, 2019, and December 31, 2018, “Other deferred credits and liabilities” on Ameren’s balance sheet included deferred compensation obligations of $78 millionand$80 million, respectively, recorded at the present value of future benefits to be paid.

Operating Revenues

As of ~~March 31,~~September 30, 2019 and 2018, our remaining performance obligations for contracts with a term greater than one year were immaterial. The Ameren Companies elected not to disclose the aggregate amount of the transaction price allocated to the performance obligations that are unsatisfied as of the end of the reporting period for contracts with an initial expected term of one year or less.

See Note 14 – Segment Information for disaggregated revenue information.

Excise Taxes

Ameren Missouri and Ameren Illinois collect from their customers excise taxes, including municipal and state excise taxes and gross receipts taxes, that are levied on the sale or distribution of natural gas and electricity. The following table presents the excise taxes recorded on a gross basis in “Operating Revenues – Electric,” “Operating Revenues – Natural gas” and “Operating Expenses – Taxes other than income taxes” on the statements of income for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:



	Three Months				Nine Months
	2019		2018		2019		2018
Ameren Missouri	$	49	$	52	$	118	$	133
Ameren Illinois	27		26		91		89
Ameren	$	76	$	78	$	209	$	222

Three Months
2019 2018
Ameren Missouri $ 31
$ 34

Ameren Illinois 39
35
^(a)
Ameren $ 70
$ 69
^(a)


~~(a)~~	~~Amounts have been adjusted from those previously reported to reflect additional excise taxes for the three months ended March 31, 2018.~~

Earnings per Share

Earnings per basic and diluted share are computed by dividing “Net Income Attributable to Ameren Common Shareholders” by the weighted-average number of basic and diluted common shares outstanding, respectively, during the applicable period. ~~Earnings~~The weighted-average shares outstanding for earnings per diluted share ~~reflects~~includes the ~~dilution that would occur if certain~~incremental effects of stock-based performance share units, ~~and~~ restricted stock units, ~~were assumed to~~and the forward sale agreement when the impact would be ~~settled.~~ dilutive, as calculated using the treasury stock method.

The following table presents Ameren’s basic and diluted earnings per share calculations and reconciles the weighted-average number of ~~performance share units and restricted stock units assumed settled was 1.5 million for both~~common shares outstanding to the ~~three months ended March 31, 2019 and 2018. There were no potentially dilutive securities excluded from the earnings per~~ diluted ~~share calculations~~weighted-average number of common shares outstanding for the three and nine months ended ~~March 31,~~September 30, 2019 and ~~2018.~~2018:



	Three Months		Nine Months
	2019	2018	2019	2018
Weighted-average Common Shares Outstanding – Basic	245.9	244.1	245.5	243.6
Assumed settlement of performance share units and restricted stock units	1.4	2.2	1.4	1.9
Dilutive effect of forward sale agreement	0.2	—	0.1	—
Weighted-average Common Shares Outstanding – Diluted^(a)	247.5	246.3	247.0	245.5


(a)	There were 0 potentially dilutive securities excluded from the earnings per diluted share calculations for the three and nine months ended September 30, 2019 and 2018.

NOTE 14 – SEGMENT INFORMATION

Ameren has ~~four~~4 segments: Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Transmission. The Ameren Missouri segment includes all of the operations of Ameren Missouri. Ameren Illinois Electric Distribution consists of the electric distribution business of Ameren Illinois. Ameren Illinois Natural Gas consists of the natural gas business of Ameren Illinois. Ameren Transmission primarily consists of the aggregated electric transmission businesses of Ameren Illinois and ATXI. The category called Other primarily includes Ameren (parent) activities and Ameren Services.

Ameren Missouri has ~~one~~1 segment. Ameren Illinois has ~~three~~3 segments: Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Illinois Transmission. See Note 1 – Summary of Significant Accounting Policies for additional information regarding the operations of Ameren Missouri, Ameren Illinois, and ATXI.

Segment operating revenues and a majority of operating expenses are directly recognized and incurred by Ameren Illinois at each Ameren Illinois segment. Common operating expenses, miscellaneous income and expenses, interest charges, and income tax expense are allocated by Ameren Illinois to each Ameren Illinois segment based on ~~certain~~ factors ~~which~~that primarily relate to the nature of the cost. Additionally, Ameren Illinois Transmission earns revenue from transmission services provided to Ameren Illinois Electric Distribution, other

retail electric suppliers, and wholesale customers. The transmission expense for Illinois customers who have elected to purchase their power from Ameren Illinois is recovered through a cost recovery mechanism with no net effect on Ameren Illinois Electric Distribution earnings, as costs are offset by corresponding revenues. Transmission revenues from these transactions are reflected in Ameren Transmission’s and Ameren Illinois Transmission’s operating revenues. An intersegment elimination at Ameren and Ameren Illinois occurs to eliminate these transmission revenues and expenses.

The following tables present revenues, net income attributable to common shareholders, and capital expenditures by segment at Ameren and Ameren Illinois for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018. Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount.

Ameren



	Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas			Ameren Transmission			Other			Intersegment Eliminations			Ameren
Three Months 2019:
External revenues	$	1,050	$	374	$	107		$	109		$	—		$	—		$	1,640
Intersegment revenues	9		15		5			19			—			(29		)	19		^(b)
Net income (loss) attributable to Ameren common shareholders	300		32		(1		)	53		^(a)	(20		)	—			364
Capital expenditures	256		139		113			129			(7		)	6			636
Three Months 2018:
External revenues	$	1,118	$	392	$	116		$	98		$	—		$	—		$	1,724
Intersegment revenues	11		—		—			15			—			(26		)	—
Net income (loss) attributable to Ameren common shareholders	294		35		—			48		^(a)	(20		)	—			357
Capital expenditures	210		135		111			124			1			(4		)	577
Nine Months 2019:
External revenues	$	2,591	$	1,118	$	563		$	303		$	—		$	—		$	4,575
Intersegment revenues	24		17		5			48			—			(75		)	19		^(b)
Net income (loss) attributable to Ameren common shareholders	446		105		57			139		^(a)	(13		)	—			734
Capital expenditures	751		390		241			377			3			(1		)	1,761
Nine Months 2018:
External revenues	$	2,848	$	1,177	$	569		$	278		$	—		$	—		$	4,872
Intersegment revenues	28		2		—			42			—			(72		)	—
Net income (loss) attributable to Ameren common shareholders	500		101		49			121		^(a)	(24		)	—			747
Capital expenditures	664		389		237			399			6			(6		)	1,689

Three Months
Ameren
Missouri
Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Other
Intersegment
Eliminations
Ameren
2019
External revenues $ 751
$ 386
$ 320
$ 99
$ —
$ —
$ 1,556

Intersegment revenues 7
1
—
15
—
(23 ) —

Net income attributable to Ameren common shareholders 39
36
57
44
^(a)
15
—
191

Capital expenditures 240
124
51
121
10
(2 ) 544

2018
External revenues $ 784
$ 399
$ 311
$ 91
$ —
$ —
$ 1,585

Intersegment revenues 8
1
—
13
—
(22 ) —

Net income attributable to Ameren common shareholders 38
33
42
37
^(a)
1
—
151

Capital expenditures 249
122
60
145
7
(4 ) 579


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

(b)

Intersegment revenues at Ameren include $14 million and $5 million of revenue from Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the three and nine months ended September 30, 2019, for a software licensing agreement with Ameren Missouri. Under authoritative accounting guidance for rate-regulated entities, the revenue recognized by Ameren Illinois was not eliminated upon consolidation. See Note 8 – Related-party Transactions under Part I, Item 1, of this report for additional information.

Ameren Illinois



	Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas			Ameren Illinois Transmission		Intersegment Eliminations			Ameren Illinois
Three Months 2019:
External revenues	$	389	$	112		$	63	$	—		$	564
Intersegment revenues	—		—			18		(18		)	—
Net income (loss) available to common shareholder	32		(1		)	34		—			65
Capital expenditures	139		113			92		—			344
Three Months 2018:
External revenues	$	392	$	116		$	56	$	—		$	564
Intersegment revenues	—		—			15		(15		)	—
Net income available to common shareholder	35		—			28		—			63
Capital expenditures	135		111			99		—			345
Nine Months 2019:
External revenues	$	1,135	$	568		$	170	$	—		$	1,873
Intersegment revenues	—		—			47		(47		)	—
Net income available to common shareholder	105		57			85		—			247
Capital expenditures	390		241			269		—			900
Nine Months 2018:
External revenues	$	1,179	$	569		$	154	$	—		$	1,902
Intersegment revenues	—		—			41		(41		)	—
Net income available to common shareholder	101		49			70		—			220
Capital expenditures	389		237			321		—			947

Three Months Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission
Intersegment
Eliminations
Ameren Illinois
2019
External revenues $ 387
$ 320
$ 55
$ —
$ 762
Intersegment revenues —
—
15
(15 ) —
Net income available to common shareholder 36
57
27
—
120
Capital expenditures 124
51
92
—
267
2018
External revenues $ 400
$ 311
$ 49
$ —
$ 760
Intersegment revenues —
—
13
(13 ) —
Net income available to common shareholder 33
42
20
—
95
Capital expenditures 122
60
118
—
300

The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018. Economic factors affect the nature, timing, amount, and uncertainty of revenues and cash flows in a similar manner across customer classes. Revenues from alternative revenue programs have a similar distribution among customer classes as revenues from contracts with customers. Other revenues not associated with contracts with customers are presented in the Other customer classification, along with electric transmission and off-system revenues.

Ameren


Three Months	Ameren Missouri			Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas			Ameren Transmission		Other		Intersegment Eliminations			Ameren
2019
																			Ameren Missouri		Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission		Intersegment Eliminations			Ameren
Three Months 2019:
Residential	$	312		$	217	$	—		$	—	$	—	$	—		$	529		$	489	$	224		$	—		$	—	$	—		$	713
Commercial	239			123		—			—		—		—			362			394		123			—			—		—			517
Industrial	55			34		—			—		—		—			89			94		27			—			—		—			121
Other	98			13		—			114		—		(23		)	202			63		15		^(a)	—			128		(29		)	177
Total electric revenues	$	704		$	387	$	—		$	114	$	—	$	(23	)	$	1,182		$	1,040	$	389		$	—		$	128	$	(29	)	$	1,528
Residential	$	38		$	—	$	246		$	—	$	—	$	—		$	284		$	8	$	—		$	65		$	—	$	—		$	73
Commercial	16			—		65			—		—		—			81			4		—			17			—		—			21
Industrial	2			—		4			—		—		—			6			1		—			2			—		—			3
Other	(2		)	—		5			—		—		—			3			6		—			28		^(a)	—		—			34
Total gas revenues	$	54		$	—	$	320		$	—	$	—	$	—		$	374		$	19	$	—		$	112		$	—	$	—		$	131
Total revenues^(a)(c)	$	758		$	387	$	320		$	114	$	—	$	(23	)	$	1,556		$	1,059	$	389		$	112		$	128	$	(29	)	$	1,659
2018
Residential	$	332		$	219	$	—		$	—	$	—	$	—		$	551
Commercial	252			124		—			—		—		—			376
Industrial	61			35		—			—		—		—			96
Other	96			22		—			104		—		(22		)	200
Total electric revenues	$	741		$	400	$	—		$	104	$	—	$	(22	)	$	1,223
Residential	$	41		$	—	$	243		$	—	$	—	$	—		$	284
Commercial	16			—		67			—		—		—			83
Industrial	2			—		6			—		—		—			8
Other	(8		)	—		(5		)	—		—		—			(13		)
Total gas revenues	$	51		$	—	$	311		$	—	$	—	$	—		$	362
Total revenues^(a)	$	792		$	400	$	311		$	104	$	—	$	(22	)	$	1,585



	Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission		Intersegment Eliminations			Ameren
Three Months 2018:
Residential	$	508		$	223		$	—		$	—	$	—		$	731
Commercial	417			131			—			—		—			548
Industrial	101			28			—			—		—			129
Other	85		^(b)	10			—			113		(26		)	182		^(b)
Total electric revenues	$	1,111		$	392		$	—		$	113	$	(26	)	$	1,590
Residential	$	8		$	—		$	68		$	—	$	—		$	76
Commercial	3			—			20			—		—			23
Industrial	1			—			1			—		—			2
Other	6			—			27			—		—			33
Total gas revenues	$	18		$	—		$	116		$	—	$	—		$	134
Total revenues^(c)	$	1,129		$	392		$	116		$	113	$	(26	)	$	1,724
Nine Months 2019:
Residential	$	1,134		$	640		$	—		$	—	$	—		$	1,774
Commercial	943			370			—			—		—			1,313
Industrial	226			94			—			—		—			320
Other	214			31		^(a)	—			351		(75		)	521
Total electric revenues	$	2,517		$	1,135		$	—		$	351	$	(75	)	$	3,928
Residential	$	56		$	—		$	399		$	—	$	—		$	455
Commercial	24			—			105			—		—			129
Industrial	3			—			9			—		—			12
Other	15			—			55		^(a)	—		—			70
Total gas revenues	$	98		$	—		$	568		$	—	$	—		$	666
Total revenues^(c)	$	2,615		$	1,135		$	568		$	351	$	(75	)	$	4,594
Nine Months 2018:
Residential	$	1,272		$	663		$	—		$	—	$	—		$	1,935
Commercial	1,033			381			—			—		—			1,414
Industrial	249			96			—			—		—			345
Other	228		^(b)	39			—			320		(72		)	515		^(b)
Total electric revenues	$	2,782		$	1,179		$	—		$	320	$	(72	)	$	4,209
Residential	$	62		$	—		$	408		$	—	$	—		$	470
Commercial	25			—			113			—		—			138
Industrial	3			—			12			—		—			15
Other	4			—			36			—		—			40
Total gas revenues	$	94		$	—		$	569		$	—	$	—		$	663
Total revenues^(c)	$	2,876		$	1,179		$	569		$	320	$	(72	)	$	4,872


(a)	Includes $14 million and $5 million for Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the three and nine months ended September 30, 2019, for a software licensing agreement with Ameren Missouri. See Note 8 – Related-party Transactions for additional information.


(b)	Includes $13 million and $60 million for the three and nine months ended September 30, 2018, respectively, for the reduction to revenue for the excess amounts collected in rates to be refunded related to the TCJA from January 1, 2018, through July 31, 2018. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K for additional information.


(c)	The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


Three Months	Ameren Missouri			Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas			Ameren Transmission			Ameren
2019
														Ameren Missouri		Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission			Ameren
Three Months 2019:
Revenues from alternative revenue programs	$	15		$	22	$	(3	)	$	(5	)	$	29	$	26	$	(145	)	$	1		$	(12	)	$	(130	)
Other revenues not from contracts with customers	5			3		1			—			9		5		1			1			—			7
2018
Three Months 2018:
Revenues from alternative revenue programs	$	(4	)	$	31	$	(3	)	$	(4	)	$	20	$	1	$	(98	)	$	(2	)	$	(12	)	$	(111	)
Other revenues not from contracts with customers	14			10		1			—			25		3		1			1			—			5



	Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission			Ameren
Nine Months 2019:
Revenues from alternative revenue programs	$	41		$	(111	)	$	2		$	(25	)	$	(93	)
Other revenues not from contracts with customers	14			5			2			—			21
Nine Months 2018:
Revenues from alternative revenue programs	$	(8	)	$	(52	)	$	(10	)	$	(21	)	$	(91	)
Other revenues not from contracts with customers	22			14			2			—			38

Ameren Illinois


Three Months	Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas			Ameren Illinois Transmission		Intersegment Eliminations			Total Ameren Illinois
2019
													Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Illinois Transmission		Intersegment Eliminations			Ameren Illinois
Three Months 2019:
Residential	$	217	$	246		$	—	$	—		$	463	$	224		$	65		$	—	$	—		$	289
Commercial	123		65			—		—			188		123			17			—		—			140
Industrial	34		4			—		—			38		27			2			—		—			29
Other	13		5			70		(15		)	73		15		^(a)	28		^(a)	81		(18		)	106
Total revenues^(a)	$	387	$	320		$	70	$	(15	)	$	762
2018
Total revenues^(b)													$	389		$	112		$	81	$	(18	)	$	564
Three Months 2018:
Residential	$	219	$	243		$	—	$	—		$	462	$	223		$	68		$	—	$	—		$	291
Commercial	124		67			—		—			191		131			20			—		—			151
Industrial	35		6			—		—			41		28			1			—		—			29
Other	22		(5		)	62		(13		)	66		10			27			71		(15		)	93
Total revenues^(a)	$	400	$	311		$	62	$	(13	)	$	760
Total revenues^(b)													$	392		$	116		$	71	$	(15	)	$	564
Nine Months 2019:
Residential													$	640		$	399		$	—	$	—		$	1,039
Commercial													370			105			—		—			475
Industrial													94			9			—		—			103
Other													31		^(a)	55		^(a)	217		(47		)	256
Total revenues^(b)													$	1,135		$	568		$	217	$	(47	)	$	1,873
Nine Months 2018:
Residential													$	663		$	408		$	—	$	—		$	1,071
Commercial													381			113			—		—			494
Industrial													96			12			—		—			108
Other													39			36			195		(41		)	229
Total revenues^(b)													$	1,179		$	569		$	195	$	(41	)	$	1,902


(a)	Includes $14 million and $5 million for Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the three and nine months ended September 30, 2019, for a software licensing agreement with Ameren Missouri. See Note 8 – Related-party Transactions for additional information.


(b)	The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:



	Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Illinois Transmission			Ameren Illinois
Three Months 2019:
Revenues from alternative revenue programs	$	(145	)	$	1		$	(12	)	$	(156	)
Other revenues not from contracts with customers	1			1			—			2
Three Months 2018:
Revenues from alternative revenue programs	$	(98	)	$	(2	)	$	(10	)	$	(110	)
Other revenues not from contracts with customers	1			1			—			2

Three Months Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois
2019
Revenues from alternative revenue programs $ 22
$ (3 ) $ (5 ) $ 14
Other revenues not from contracts with customers 3
1
—
4
2018
Revenues from alternative revenue programs $ 31
$ (3 ) $ (4 ) $ 24
Other revenues not from contracts with customers 10
1
—
11



	Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Illinois Transmission			Ameren Illinois
Nine Months 2019:
Revenues from alternative revenue programs	$	(111	)	$	2		$	(26	)	$	(135	)
Other revenues not from contracts with customers	5			2			—			7
Nine Months 2018:
Revenues from alternative revenue programs	$	(52	)	$	(10	)	$	(19	)	$	(81	)
Other revenues not from contracts with customers	14			2			—			16

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

The following discussion should be read in conjunction with the financial statements contained in this Form 10-Q, as well as Management’s Discussion and Analysis of Financial Condition and Results of Operations and Risk Factors contained in the Form 10-K. We intend for this discussion to provide the reader with information that will assist in understanding our financial statements, the changes in certain key items in those financial statements, and the primary factors that accounted for those changes, as well as how certain accounting principles affect our financial statements. The discussion also provides information about the financial results of our business segments to provide a better understanding of how those segments and their results affect the financial condition and results of operations of Ameren as a whole. Also see the Glossary of Terms and Abbreviations at the front of this report and in the Form 10-K.

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


•	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.

Ameren’s financial statements are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been ~~eliminated.~~ eliminated, except as disclosed in Note 8 – Related-party Transactions, under Part I, Item 1, of this report. Ameren Missouri and Ameren Illinois have no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.

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

OVERVIEW

~~Ameren's first quarter 2019 net~~Net income attributable to Ameren common shareholders in the three months ended September 30, 2019, was ~~$191~~$364 million, or ~~78 cents~~$1.47 per diluted share, compared with ~~first quarter 2018 net~~$357 million, or $1.45 per diluted share, in the year-ago period. Net income attributable to Ameren common shareholders ~~of $151~~in the nine months ended September 30, 2019, was $734 million, or ~~62 cents~~$2.97 per diluted ~~share. The increase~~share, compared with $747 million, or $3.04 per diluted share, in ~~year-over-year earnings reflected~~ the ~~benefits of~~year-ago period. Net income for the three and nine months ended September 30, 2019, compared to the year-ago periods, was unfavorably affected by milder summer temperatures experienced in 2019 and increased ~~infrastructure investments, which contributed to higher net income~~property taxes, both primarily at ~~each of Ameren’s business segments.~~Ameren Missouri, and a lower recognized return on equity at Ameren Illinois Electric Distribution. Earnings in both periods were also unfavorably affected by increased depreciation and amortization expenses at Ameren Illinois Natural Gas ~~earnings~~and Ameren Missouri. Net income for the three and nine months ended September 30, 2019, compared to the year-ago periods, was favorably affected by the benefit of MEEIA performance incentives and increased ~~as a result of higher delivery service rates and a change in rate design, which concentrates more revenues in the winter heating season due to an increase in volumetric rates. Increased~~ infrastructure investments ~~drove higher earnings~~ at Ameren Transmission and Ameren Illinois Electric Distribution, each of which benefits from formulaic ratemaking. ~~Ameren Missouri~~Earnings in both periods were also favorably affected by the absence of a noncash charge to earnings ~~also rose reflecting higher weather-driven electric retail sales and energy-efficiency performance incentives that offset~~for the ~~comparative impacts~~revaluation of ~~timing differences~~deferred taxes recorded in 2018 ~~between income tax expense and revenue reductions~~ related to ~~federal tax reform. This timing difference will affect~~the TCJA. Net income for the nine months ended September 30, 2019, ~~quarterly~~compared to the year-ago period, was unfavorably affected by increased operation and maintenance expenses related to the Callaway energy center’s scheduled refueling and maintenance outage that was completed in May 2019, partially offset by increased earnings ~~comparisons but is not expected to affect the full-year comparison. The first quarter earnings comparison also benefited from~~at Ameren Illinois Natural Gas as a ~~lower consolidated effective income tax rate.~~result of higher delivery service rates.

Ameren’s strategic plan includes investing in, and operating its utilities in, a manner consistent with existing regulatory frameworks, enhancing those frameworks, and advocating for responsible energy and economic policies, as well as creating and capitalizing on opportunities for investment for the benefit of its customers and shareholders. Ameren remains focused on disciplined cost management and

strategic capital allocation. Ameren believes it has constructive regulatory frameworks for investment at all of its utility businesses and invested ~~over $0.5~~$1.8 billion in those businesses in the ~~three~~nine months ended ~~March 31,~~September 30, 2019.

In ~~May~~August 2019, Ameren ~~Missouri~~ entered into a ~~build-transfer~~forward sale agreement with a ~~subsidiary~~counterparty relating to 7.5 million shares of ~~Enel Green Power North America, Inc.~~common stock. The forward sale agreement can be settled at Ameren’s discretion on or prior to ~~acquire, after construction, an up-to 300-megawatt wind generation facility~~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 ~~located~~physically settled unless Ameren elects to settle in ~~northwestern Missouri.~~cash or to net share settle.If physically settled, Ameren ~~Missouri~~ expects to ~~file~~receive between $540 million and $550 million upon settlement. See Note 4 – Long-Term Debt and Equity Financings under Part I, Item 1, of this report for a certificate of convenience and necessity with the MoPSC in May 2019. Final RTO interconnection costs are expected to be determined in June 2019, and a related RTO transmission interconnection agreement is expected in the fall of 2019.additional information.

In 2018, Ameren Missouri entered into two build-transfer agreements to acquire, after construction, an up-to 400-megawatt wind generation facility and an up-to 157-megawatt wind generation facility. In October 2018, the MoPSC issued an order approving a unanimous stipulation and agreement regarding a requested certificate of convenience and necessity for the up-to 400-megawatt facility. In March 2019, the MoPSC issued an order approving a nonunanimous stipulation and agreement regarding a requested certificate of convenience and necessity for the up-to 157-megawatt facility. Final MISO interconnection costs for the up-to 400-megawatt facility are expected to be determined in June 2019, and a related transmission interconnection agreement with the MISO is expected in the fall of 2019. Final MISO interconnection costs for the up-to 157-megawatt facility are expected to be determined in the fall of 2019, and a related transmission interconnection agreement with the MISO is expected in early 2020.

~~The three build-transfer agreements collectively represent approximately $1.4 billion of capital expenditures expected in 2020.~~The MoPSC has approved a RESRAM, which is designed to mitigate the impacts of regulatory lag for the cost of compliance with renewable energy standards, including recovery of investments in wind and other renewable generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA.

In January 2019, Ameren Missouri recognized MEEIA 2013 and MEEIA 2016 performances incentives totaling $20 million. The MEEIA 2019 plan began in March 2019. 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 regulatory recovery mechanism. Ameren Missouri intends to invest $226 million over the life of the plan, including $65 million per year through 2021. 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, including $30 million if 100% of the goals are achieved during the period ended December 2021. Additional revenues may be earned if Ameren Missouri exceeds 100% of its energy savings goals.

In February 2019, Ameren Missouri announced its Smart Energy Plan, which includes a five-year capital investment overview with a detailed one-year plan for ~~2019,~~2019. The plan is designed to upgrade Ameren Missouri's electric ~~infrastructure. The plan~~infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $6.3 billion over the five-year period from 2019 through 2023, with ~~costs~~expenditures largely recoverable under PISA and ~~for the portion of wind and other renewable generation investments that are not recoverable under PISA, recoverable under~~ the RESRAM.

In March 2019, Ameren issued its Building a Cleaner Energy Future report, which ~~provides~~sets forth Ameren's plan for reducing carbon emissions and addressing climate risk. The plan is largely reflected in the Ameren Missouri 2017 ~~IRP.~~IRP, which includes expanding renewable sources by adding 700 megawatts of wind generation by the end of 2020 and adding 100 megawatts of solar generation by 2027. Ameren Missouri expects to file its next IRP in September 2020.

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 the end of 2020.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.

In May 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.The two build-transfer agreements, which are subject to customary contract terms and conditions, collectively represent approximately $1.2 billion of capital expenditures, are expected to be completed by the end of 2020, 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.The MoPSC has approved a RESRAM, which is designed to mitigate the impacts of regulatory lag for the cost of compliance with Missouri’s renewable energy standard, including recovery of investments in wind and other renewable energy generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for more information regarding Ameren Missouri wind generation facilities.

In July 2019, Ameren Missouri filed a request with the MoPSC seeking approval to decrease its annual revenues for electric service by $1 million. The electric rate decrease request is based on a 9.95% return on common equity, a capital structure composed of51.9%common equity, a rate base of $8.0 billion, and a test year ended December 31, 2018, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2019. Pro-forma adjustments are also expected for fuel costs, transportation costs, MISO multi-value transmission project expenses, and payroll costs effective as of January 1, 2020.The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by late April 2020 and new rates effective by late May 2020. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information.

In August 2019, the MoPSC issued an order approving a stipulation and agreement to decrease Ameren Missouri’s annual revenues for natural gas delivery service by $1 million. The decrease in annual rates is based on a return on common equity range of 9.4% to 9.95% and a capital structure composed of 52.0% common equity, which was Ameren Missouri’s capital structure as of May 31, 2019. This order allows for the use of ISRS, which will be calculated using an ROE of 9.725%. The order represents a $1 million increase to Ameren Missouri’s annual revenues for natural gas delivery service from interim rates, which were approved by the MoPSC in December 2018.The new rates became effective September 1, 2019.

distribution service rates, beginning in January 2020.This update reflects an increase to the annual formula rate based on 2018 actual costs and expected net plant additions for 2019, and an increase to include the 2018 revenue requirement reconciliation adjustment. It also reflects a decrease for the conclusion of the 2017 revenue requirement reconciliation adjustment, which will be fully collected from customers in 2019, consistent with the ICC’s November 2018 annual update filing order. It also reflects an increase to the annual formula rate based on 2018 actual costs and expected net plant additions for 2019, and an increase to include the 2018 revenue requirement reconciliation adjustment. In August 2019, the ICC staff submitted an updated calculation of the revenue requirement included in Ameren Illinois’ filing, recommending an amount comparable to that included in Ameren Illinois’ filing. In October 2019, the administrative law judges issued a proposed order consistent with Ameren Illinois’ filing. An ICC decision in this proceeding is expected by December 2019.

ATXI continues to make progress with construction activities for its two MISO-approved multi-value projects that are still under construction: the Illinois Rivers and Mark Twain projects. Construction of the Illinois Rivers project is substantially complete, with the last section expected to be completed in 2020.In June 2019, a section of the Mark Twain project was completed from Kirksville, Missouri to the Iowa border, and the remaining section is expected to be completed by the end of 2019.

RESULTS OF OPERATIONS

Our results of operations and financial position are affected by many factors. Economic conditions, energy-efficiency investments by our customers and by us, and the actions of key customers can significantly affect the demand for our services. Ameren and Ameren Missouri results are also affected by seasonal fluctuations in winter heating and summer cooling demands, as well as by nuclear refueling and other energy center maintenance outages. Additionally, fluctuations in interest rates and conditions in the capital and credit markets affect our cost of borrowing and our pension and postretirement benefits costs. Almost all of Ameren’s revenues are subject to state or federal regulation.

This regulation has a material impact on the prices we charge for our services. Our results of operations, financial position, and liquidity are affected by our ability to align our overall spending, both operating and capital, within the frameworks established by our regulators.

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

Ameren Missouri’s electric service and natural gas distribution service rates are established in a traditional regulatory rate review based on a historical test year and an allowed return on equity. To mitigate the effects of regulatory lag, Ameren Missouri has recovery mechanisms in place for certain costs that allow customer rates to be adjusted without a traditional regulatory rate review. Ameren Missouri’s FAC cost recovery mechanism allows it to recover or refund, through customer rates, 95% of the variance in net energy costs from the amount set in base rates without a traditional regulatory rate review, subject to MoPSC prudence reviews, with the remaining 5% of changes retained by Ameren Missouri. Net recovery of these costs through customer rates does not affect Ameren Missouri’s electric margins, as any change in revenue is offset by a corresponding change in fuel expense. In addition, Ameren Missouri’s MEEIA customer energy-efficiency program costs, the related lost electric margins, and any performance incentive are recoverable through the MEEIA cost recovery mechanism without a traditional regulatory rate review. Ameren Missouri also has a cost recovery mechanism for natural gas purchased on behalf of its customers. These pass-through purchased gas costs do not affect Ameren Missouri’s natural gas margins, as any change in costs is offset by a corresponding change in revenues. Ameren Missouri employs other cost recovery mechanisms, including a pension and postretirement benefit cost tracker, an uncertain tax position tracker, a tracker on certain excess deferred taxes, a renewable energy standards cost tracker, and a solar rebate program tracker. Each of these trackers allows Ameren Missouri to defer the difference between actual costs incurred and costs included in customer rates as a regulatory asset or regulatory liability. The difference will be reflected in base rates in a subsequent MoPSC rate order.

Pursuant to its PISA election, Ameren Missouri is permitted to defer and recover 85% of the depreciation expense and a weighted average cost of capital return on rate base on certain property, plant, and equipment placed in service after September 1, 2018, and not included in base rates. Accumulated PISA deferrals earn carrying costs at the weighted-average cost of capital, 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 ~~weighted average~~weighted-average cost of capital return for renewable generation plant placed in service and not recovered under PISA. ~~In January 2019,~~Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. PISA and the ~~MoOPC filed an appeal with~~RESRAM mitigate the ~~Missouri Court~~effects of ~~Appeals, Western District, challenging~~regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under PISA and the ~~MoPSC’s December 2018 order allowing~~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 ~~to recover, through~~recognizes the ~~RESRAM,~~cost of debt on PISA deferrals in revenue, instead of using the ~~15% of depreciation expense and~~ weighted average cost of capital, ~~return not recovered under PISA for renewable generation.~~both debt and equity, which will ultimately be recognized in revenues when recovery of such deferrals are reflected in customer rates. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report ~~for additional information.~~regarding a MoOPC appeal related to the RESRAM.

Ameren Illinois’ electric distribution service rates are reconciled annually to its actual revenue requirement, year-end rate base and capital structure, and allowed return on equity, under a formula ratemaking process, effective through 2022. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the year. In addition, Ameren Illinois’ electric customer energy-efficiency rider provides Ameren Illinois’ electric distribution service business with recovery of, and return on, energy-efficiency investments. Under formula ratemaking for both its electric distribution service and its electric energy-efficiency investments, the revenue requirements are based on recoverable costs, year-end rate base, a capital structure of 50% common equity, and a return on equity. The return on equity component is equal to the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. Therefore, Ameren Illinois’ annual return on equity for its electric distribution business is directly correlated to the yields on such bonds.

Ameren Illinois’ natural gas distribution service rates are established in a traditional regulatory rate review based on a future test year and allowed return on equity. Ameren Illinois employs a VBA to ensure recoverability of the natural gas distribution service revenue requirement for residential and small nonresidential customers that is dependent on sales volumes. For these rate classes, the VBA allows Ameren Illinois to adjust natural gas distribution service rates without a traditional regulatory rate review when changes occur in sales volumes from normalized sales volumes approved by the ICC in a previous regulatory rate review. In addition, the QIP rider provides Ameren Illinois’ natural gas business with recovery of, and a return on, qualifying infrastructure plant investments that are placed in service between regulatory rate reviews.

Ameren Illinois also has recovery mechanisms in place for certain costs that allow customer rates to be adjusted without a traditional regulatory rate review. Ameren Illinois’ electric distribution service business has cost recovery mechanisms for power purchased and transmission services incurred on behalf of its customers, renewable energy credit compliance, and zero emission credits. Ameren Illinois’ natural gas business has a cost recovery mechanism for natural gas purchased on behalf of its customers. These pass-through costs do not affect Ameren Illinois’ electric or natural gas margins, as any change in costs is offset by a corresponding change in revenues. Ameren Illinois employs other cost recovery mechanisms for natural gas customer energy-efficiency program costs and certain environmental costs, as well as bad debt expenses and costs of certain asbestos-related claims not recovered in base rates.

FERC’s electric transmission formula rate framework provides for an annual reconciliation of the electric transmission service revenue requirement, which reflects the actual recoverable costs incurred and the 13-month average rate base for a given year, with the revenue requirement in customer rates, including an allowed return on equity. Ameren Illinois and ATXI use a company-specific, forward-looking formula ratemaking framework in setting their transmission rates. These rates are updated each January with forecasted information. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement. The regulatory balance is collected from, or refunded to, customers within two years from the end of the year. The total return on equity currently allowed for Ameren Illinois’ and ATXI’s electric transmission service businesses is 10.82% and is subject to a FERC complaint case. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information.

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

Earnings Summary

The following table presents a summary of Ameren’s earnings for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Three Months				Three Months				Nine Months
	2019		2018		2019		2018		2019		2018
Net income attributable to Ameren common shareholders	$	191	$	151	$	364	$	357	$	734	$	747
Earnings per common share – basic and diluted	0.78		0.62
Earnings per common share – diluted					1.47		1.45		2.97		3.04

Net income attributable to Ameren common shareholders increased ~~$40~~$7 million, or 162 cents per diluted share, in the three months ended ~~March 31,~~September 30, 2019, compared with the year-ago period. The increase was ~~primarily~~ due to net income increases of ~~$15~~$6 million ~~$14~~and $5 million ~~$7 million,~~at Ameren Missouri and Ameren Transmission, respectively. These increases were partially offset by a net income decrease of $3 million at Ameren Illinois Electric Distribution and a net loss of $1 million at Ameren Illinois Natural Gas, compared with no net income or loss in the year-ago period.

Net income attributable to Ameren common shareholders decreased $13 million, or 7 cents per diluted share, in the nine months ended September 30, 2019, compared with the year-ago period. The decrease was due to a net income decrease of $54 million at Ameren Missouri,

partially offset by net income increases of $18 million, $8 million, and $4 million at Ameren Transmission, Ameren Illinois Natural Gas, and Ameren Illinois Electric Distribution, respectively, and a reduction in the net loss for activity not reported as part of a segment, primarily at Ameren (parent), ~~Ameren Transmission, and Ameren Illinois Electric Distribution, respectively.~~of $11 million.

Earnings per diluted share were ~~favorably~~unfavorably affected in the three and nine months ended ~~March 31,~~September 30, 2019, compared to the year-ago periods (except where a specific period is referenced), by:

~~the recognition of MEEIA 2013~~decreased electric retail sales at Ameren Missouri, primarily due to milder summer temperatures experienced in 2019 (estimated at 4 cents and ~~MEEIA 2016 performance incentives (5~~23 cents per ~~share)~~share, respectively);

increased other operation and maintenance expenses related to the Callaway energy center’s scheduled refueling and maintenance outage that was completed in May 2019 (9 cents per share for the nine months ended September 30, 2019);

increased taxes other than income taxes, primarily at Ameren Missouri, due to higher property taxes (2 cents and 5 cents per share, respectively);

increased depreciation and amortization expenses not subject to riders or regulatory tracking mechanisms at Ameren Illinois Natural Gas and Ameren Missouri, primarily due to additional property, plant, and equipment (1 cent and 5 cents per share, respectively);

decreased margins at Ameren Illinois Natural Gas, due to a change in rate design pursuant to the ICC's November 2018 natural gas rate order, ~~which will partially reverse by year-end due to a change in rate design,~~ which concentrates more revenues in the winter heating season due to an increase in volumetric rates (3 cents per share for the three months ended September 30, 2019);

decreased Ameren Illinois Electric Distribution earnings under formula ratemaking due to a lower recognized return on equity (1 cent and 3 cents per share, respectively); and

increased weighted-average basic common shares outstanding (1 cent and 2 cents per share, respectively).

Earnings per diluted share were favorably affected in the three and nine months ended September 30, 2019, compared to the year-ago periods (except where a specific period is referenced), by:

the recognition of MEEIA 2013 and MEEIA 2016 performance incentives (5 cents and 10 cents per share, respectively);

increased Ameren Transmission and Ameren Illinois Electric Distribution earnings under formula ratemaking due to additional rate base investment and Ameren Illinois Electric Distribution energy-efficiency investments (3 cents and 9 cents per share, respectively);

the absence of a noncash charge to earnings for the revaluation of deferred taxes recorded in 2018 related to the TCJA (5 cents per ~~share)~~share for both periods);

increased ~~electric retail sales at Ameren Missouri~~other income, net, primarily due ~~in part,~~ to ~~colder winter temperatures experienced in 2019 (3~~increased non-service cost components of net periodic benefit income and decreased donations (2 cents and 4 cents per ~~share)~~share, respectively);

a decrease in the effective income tax rate primarily due to an increase in the income tax benefit recorded at Ameren (parent) related to stock-based compensation (3 cents per ~~share)~~share for the nine months ended September 30, 2019);

~~decreased interim period income tax expense, primarily~~an increase in base rates at Ameren ~~(parent), which is not expected~~Illinois Natural Gas pursuant to ~~materially affect year-over-year earnings (3~~the ICC's November 2018 natural gas rate order (2 cents per ~~share);~~

~~increased Ameren Transmission and Ameren Illinois Electric Distribution earnings under formula ratemaking, primarily due to additional rate base investment (3 cents per share)~~share for the nine months ended September 30, 2019);

decreased financing costs at Ameren Missouri, primarily due to the regulatory deferral of interest expense ~~under~~pursuant to PISA and lower interest rates, partially offset by lower levels of the allowance for funds used during construction (2 cents per share for the nine months ended September 30, 2019);

increased Ameren Illinois Natural Gas earnings from investments in qualifying infrastructure recovered under the QIP rider (1 cent per ~~share)~~share for the nine months ended September 30, 2019); and

decreased other operation and maintenance expenses not subject to riders or regulatory tracking mechanisms, excluding 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 ~~largely offset by higher electric distribution maintenance costs and costs related to the Callaway energy center’s scheduled refueling and maintenance outage that began in April 2019~~ (1 cent per ~~share).~~

~~Earnings per diluted~~ share ~~were unfavorably affected in~~for the ~~three~~nine months ended ~~March 31, 2019, compared to the year-ago period by:~~

decreased earnings at Ameren Missouri due to the impact of timing differences in 2018 between income tax expense and revenue reductions associated with the TCJA, which affects interim period earnings comparisons but is not expected to materially affect year-over-year earnings (8 cents per share);

increased depreciation and amortization expenses not subject to riders or regulatory tracking mechanisms at Ameren Missouri and Ameren Illinois Natural Gas resulting from additional property, plant, and equipment (2 cents per share); and

~~increased weighted-average basic common shares outstanding (1 cent per share)~~September 30, 2019).

The cents per share information presented is based on the weighted-average basic common shares outstanding in the three and nine months ended ~~March 31,~~September 30, 2018, and does not reflect any change in earnings per share resulting from dilution, unless otherwise noted. Amounts other

than variances related to income taxes have been presented net of income taxes using Ameren’s 2019 statutory tax rate of 27%. For additional details regarding the Ameren Companies’ results of operations, including explanations of Electric and Natural Gas Margins, Other Operations and Maintenance Expenses, Depreciation and Amortization, Taxes Other Than Income Taxes, Other Income, Net, Interest Charges, and Income Taxes, see the major headings below.

Below is Ameren’s table of income statement components by segment for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission			Other / Intersegment Eliminations			Total			Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission			Other / Intersegment Eliminations			Total
Three Months 2019:
Electric margins	$	493		$	267		$	—		$	114		$	(8	)	$	866		$	844		$	270		$	—		$	128		$	(9	)	$	1,233
Natural gas margins	27			—			186			—			—			213			13			—			87			—			—			100
Other operations and maintenance	(224		)	(119		)	(59		)	(15		)	—			(417		)	(242		)	(128		)	(52		)	(15		)	3			(434		)
Depreciation and amortization	(140		)	(68		)	(20		)	(20		)	—			(248		)	(138		)	(68		)	(20		)	(21		)	(1		)	(248		)
Taxes other than income taxes	(77		)	(20		)	(24		)	(1		)	(4		)	(126		)	(96		)	(22		)	(10		)	(1		)	(2		)	(131		)
Other income, net	12			6			3			1			7			29			15			9			3			2			5			34
Interest charges	(47		)	(18		)	(10		)	(19		)	(3		)	(97		)	(44		)	(19		)	(9		)	(20		)	(4		)	(96		)
Income (taxes) benefit	(4		)	(11		)	(19		)	(16		)	23			(27		)
Net income	40			37			57			44			15			193
Income taxes																			(51		)	(10		)	—			(19		)	(12		)	(92		)
Net income (loss)																			301			32			(1		)	54			(20		)	366
Noncontrolling interests – preferred stock dividends	(1		)	(1		)	—			—			—			(2		)	(1		)	—			—			(1		)	—			(2		)
Net income attributable to Ameren common shareholders	$	39		$	36		$	57		$	44		$	15		$	191
Net income (loss) attributable to Ameren common shareholders																			$	300		$	32		$	(1	)	$	53		$	(20	)	$	364
Three Months 2018:
Electric margins	$	511		$	263		$	—		$	104		$	(6	)	$	872		$	846		$	272		$	—		$	113		$	(5	)	$	1,226
Natural gas margins	27			—			164			—			—			191			13			—			91			—			—			104
Other operations and maintenance	(232		)	(125		)	(60		)	(16		)	2			(431		)	(234		)	(126		)	(56		)	(16		)	3			(429		)
Depreciation and amortization	(136		)	(63		)	(15		)	(18		)	(2		)	(234		)	(137		)	(65		)	(16		)	(20		)	(3		)	(241		)
Taxes other than income taxes	(80		)	(17		)	(23		)	(1		)	(4		)	(125		)	(94		)	(21		)	(11		)	1			(2		)	(127		)
Other income, net	13			3			1			2			4			23			16			7			2			2			5			32
Interest charges	(51		)	(18		)	(10		)	(19		)	(3		)	(101		)	(50		)	(19		)	(9		)	(19		)	(4		)	(101		)
Income taxes																			(65		)	(13		)	(1		)	(13		)	(13		)	(105		)
Net income (loss)																			295			35			—			48			(19		)	359
Noncontrolling interests – preferred stock dividends																			(1		)	—			—			—			(1		)	(2		)
Net income (loss) attributable to Ameren common shareholders																			$	294		$	35		$	—		$	48		$	(20	)	$	357
Nine Months 2019:
Electric margins																			$	1,948		$	804		$	—		$	351		$	(24	)	$	3,079
Natural gas margins																			57			—			373			—			—			430
Other operations and maintenance																			(720		)	(373		)	(170		)	(44		)	6			(1,301		)
Depreciation and amortization																			(417		)	(204		)	(59		)	(62		)	(3		)	(745		)
Taxes other than income taxes																			(256		)	(61		)	(47		)	(3		)	(8		)	(375		)
Other income, net																			43			25			9			6			16			99
Interest charges																			(136		)	(54		)	(28		)	(58		)	(14		)	(290		)
Income (taxes) benefit	(13		)	(9		)	(15		)	(15		)	10			(42		)	(70		)	(31		)	(20		)	(50		)	13			(158		)
Net income	39			34			42			37			1			153
Net income (loss)																			449			106			58			140			(14		)	739
Noncontrolling interests – preferred stock dividends	(1		)	(1		)	—			—			—			(2		)	(3		)	(1		)	(1		)	(1		)	1			(5		)
Net income attributable to Ameren common shareholders	$	38		$	33		$	42		$	37		$	1		$	151
Net income (loss) attributable to Ameren common shareholders																			$	446		$	105		$	57		$	139		$	(13	)	$	734
Nine Months 2018:
Electric margins																			$	2,061		$	804		$	—		$	320		$	(19	)	$	3,166
Natural gas margins																			57			—			354			—			—			411
Other operations and maintenance																			(707		)	(380		)	(170		)	(48		)	6			(1,299		)
Depreciation and amortization																			(411		)	(193		)	(48		)	(57		)	(4		)	(713		)
Taxes other than income taxes																			(258		)	(59		)	(47		)	(3		)	(7		)	(374		)
Other income, net																			45			18			7			5			9			84
Interest charges																			(152		)	(56		)	(28		)	(56		)	(10		)	(302		)
Income (taxes) benefit																			(132		)	(32		)	(18		)	(40		)	1			(221		)
Net income (loss)																			503			102			50			121			(24		)	752
Noncontrolling interests – preferred stock dividends																			(3		)	(1		)	(1		)	—			—			(5		)
Net income (loss) attributable to Ameren common shareholders																			$	500		$	101		$	49		$	121		$	(24	)	$	747

Below is Ameren Illinois’ table of income statement components by segment for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Illinois Transmission			Total			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Illinois Transmission			Total
Three Months 2019:
Electric and natural gas margins	$	267		$	186		$	70		$	523		$	270		$	87		$	81		$	438
Other operations and maintenance	(119		)	(59		)	(13		)	(191		)	(128		)	(52		)	(13		)	(193		)
Depreciation and amortization	(68		)	(20		)	(13		)	(101		)	(68		)	(20		)	(14		)	(102		)
Taxes other than income taxes	(20		)	(24		)	(1		)	(45		)	(22		)	(10		)	(1		)	(33		)
Other income, net	6			3			2			11			9			3			1			13
Interest charges	(18		)	(10		)	(9		)	(37		)	(19		)	(9		)	(10		)	(38		)
Income taxes	(11		)	(19		)	(9		)	(39		)	(10		)	—			(10		)	(20		)
Net income	37			57			27			121
Preferred stock dividends	(1		)	—			—			(1		)
Net income (loss) attributable to common shareholder													$	32		$	(1	)	$	34		$	65
Three Months 2018:
Electric and natural gas margins													$	272		$	91		$	71		$	434
Other operations and maintenance													(126		)	(56		)	(13		)	(195		)
Depreciation and amortization													(65		)	(16		)	(13		)	(94		)
Taxes other than income taxes													(21		)	(11		)	—			(32		)
Other income, net													7			2			2			11
Interest charges													(19		)	(9		)	(10		)	(38		)
Income taxes													(13		)	(1		)	(9		)	(23		)
Net income attributable to common shareholder	$	36		$	57		$	27		$	120		$	35		$	—		$	28		$	63
Three Months 2018:
Nine Months 2019:
Electric and natural gas margins	$	263		$	164		$	62		$	489		$	804		$	373		$	217		$	1,394
Other operations and maintenance	(125		)	(60		)	(14		)	(199		)	(373		)	(170		)	(37		)	(580		)
Depreciation and amortization	(63		)	(15		)	(12		)	(90		)	(204		)	(59		)	(41		)	(304		)
Taxes other than income taxes	(17		)	(23		)	(1		)	(41		)	(61		)	(47		)	(2		)	(110		)
Other income, net	3			1			2			6			25			9			5			39
Interest charges	(18		)	(10		)	(9		)	(37		)	(54		)	(28		)	(29		)	(111		)
Income taxes	(9		)	(15		)	(8		)	(32		)	(31		)	(20		)	(28		)	(79		)
Net income	34			42			20			96			106			58			85			249
Preferred stock dividends	(1		)	—			—			(1		)	(1		)	(1		)	—			(2		)
Net income attributable to common shareholder	$	33		$	42		$	20		$	95		$	105		$	57		$	85		$	247
Nine Months 2018:
Electric and natural gas margins													$	804		$	354		$	195		$	1,353
Other operations and maintenance													(380		)	(170		)	(40		)	(590		)
Depreciation and amortization													(193		)	(48		)	(37		)	(278		)
Taxes other than income taxes													(59		)	(47		)	(2		)	(108		)
Other income, net													18			7			5			30
Interest charges													(56		)	(28		)	(28		)	(112		)
Income taxes													(32		)	(18		)	(23		)	(73		)
Net income													102			50			70			222
Preferred stock dividends													(1		)	(1		)	—			(2		)
Net income attributable to common shareholder													$	101		$	49		$	70		$	220

Electric and Natural Gas Margins

The following table presents the favorable (unfavorable) variations by Ameren segment for electric and natural gas margins for the three and nine months ended ~~March 31,~~September 30, 2019, compared with the year-ago ~~period.~~periods. Electric margins are defined as electric revenues less fuel and purchased power costs. Natural gas margins are defined as natural gas revenues less natural gas purchased for resale. We consider electric and natural gas margins useful measures to analyze the change in profitability of our electric and natural gas operations between periods. We have included the analysis below ~~as a~~to complement to the financial information we provide in accordance with GAAP. However, these margins may not be a presentation defined under GAAP, and they may not be comparable to other companies’ presentations or more useful than the GAAP information we provide elsewhere in this report.


Three Months	Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission^(a)		Other / Intersegment Eliminations			Ameren			Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission^(a)		Other / Intersegment Eliminations			Ameren
Electric revenue change:
Effect of weather (estimate)^(b)	$	3		$	—		$	—		$	—	$	—		$	3		$	(8	)	$	—		$	—		$	—	$	—		$	(8	)
Base rates (estimate)^(c)	(33		)	4			—			10		—			(19		)	(4		)	(6		)	—			15		—			5
Recovery of power restoration efforts provided to other utilities	(9		)	(7		)	—			—		—			(16		)
Sales volume (excluding the estimated effects of weather and MEEIA)	1			—			—			—		—			1
Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)																		(6		)	—			—			—		—			(6		)
MEEIA 2013 and MEEIA 2016 performance incentives	15			—			—			—		—			15			18			—			—			—		—			18
Off-system sales	(20		)	—			—			—		—			(20		)	(50		)	—			—			—		—			(50		)
Energy-efficiency program investments	—			4			—			—		—			4			—			4			—			—		—			4
Other	7			3			—			—		(1		)	9			1			1			—			—		(3		)	(1		)
Cost recovery mechanisms – offset in fuel and purchased power^(d)	(1		)	(17		)	—			—		—			(18		)	(20		)	(1		)	—			—		—			(21		)
Other cost recovery mechanisms^(e)																		(2		)	(1		)	—			—		—			(3		)
Total electric revenue change	$	(37	)	$	(13	)	$	—		$	10	$	(1	)	$	(41	)	$	(71	)	$	(3	)	$	—		$	15	$	(3	)	$	(62	)
Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather)	$	20		$	—		$	—		$	—	$	—		$	20		$	52		$	—		$	—		$	—	$	—		$	52
Effect of weather (estimate)^(b)	(1		)	—			—			—		—			(1		)	1			—			—			—		—			1
Other	(1		)	—			—			—		(1		)	(2		)	(4		)	—			—			—		(1		)	(5		)
Cost recovery mechanisms – offset in electric revenue^(d)	1			17			—			—		—			18			20			1			—			—		—			21
Total fuel and purchased power change	$	19		$	17		$	—		$	—	$	(1	)	$	35		$	69		$	1		$	—		$	—	$	(1	)	$	69
Net change in electric margins	$	(18	)	$	4		$	—		$	10	$	(2	)	$	(6	)	$	(2	)	$	(2	)	$	—		$	15	$	(4	)	$	7
Natural gas revenue change:
Effect of weather (estimate)^(b)	$	2		$	—		$	—		$	—	$	—		$	2
Base rates (estimate)	—			—			6			—		—			6
Change in rate design	—			—			12			—		—			12			—			—			(8		)	—		—			(8		)
QIP rider																		—			—			2			—		—			2
Software licensing agreement																		—			—			5			—		—			5
Other	—			—			1			—		—			1			—			—			(2		)	—		—			(2		)
Cost recovery mechanisms – offset in natural gas purchased for resale^(d)	1			—			(13		)	—		—			(12		)	1			—			—			—		—			1
Other cost recovery mechanisms^(e)	—			—			3			—		—			3			—			—			(1		)	—		—			(1		)
Total natural gas revenue change	$	3		$	—		$	9		$	—	$	—		$	12		$	1		$	—		$	(4	)	$	—	$	—		$	(3	)
Natural gas purchased for resale change:
Effect of weather (estimate)^(b)	$	(2	)	$	—		$	—		$	—	$	—		$	(2	)
Cost recovery mechanisms – offset in natural gas revenue^(d)	(1		)	—			13			—		—			12			(1		)	—			—			—		—			(1		)
Total natural gas purchased for resale change	$	(3	)	$	—		$	13		$	—	$	—		$	10		$	(1	)	$	—		$	—		$	—	$	—		$	(1	)
Net change in natural gas margins	$	—		$	—		$	22		$	—	$	—		$	22		$	—		$	—		$	(4	)	$	—	$	—		$	(4	)



Nine Months	Ameren Missouri			Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas			Ameren Transmission^(a)		Other / Intersegment Eliminations			Ameren
Electric revenue change:
Effect of weather (estimate)^(b)	$	(100	)	$	—		$	—		$	—	$	—		$	(100	)
Base rates (estimate)^(c)	(39		)	(2		)	—			31		—			(10		)
Recovery of power restoration efforts provided to other utilities	(11		)	(9		)	—			—		—			(20		)
Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)	7			—			—			—		—			7
MEEIA 2013 and MEEIA 2016 performance incentives	33			—			—			—		—			33
Off-system sales	(101		)	—			—			—		—			(101		)
Energy-efficiency program investments	—			11			—			—		—			11
Other	—			3			—			—		(3		)	—
Cost recovery mechanisms – offset in fuel and purchased power^(d)	(37		)	(44		)	—			—		—			(81		)
Other cost recovery mechanisms^(e)	(17		)	(3		)	—			—		—			(20		)
Total electric revenue change	$	(265	)	$	(44	)	$	—		$	31	$	(3	)	$	(281	)
Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather)	$	104		$	—		$	—		$	—	$	—		$	104
Effect of weather (estimate)^(b)	15			—			—			—		—			15
Transmission services charges	(5		)	—			—			—		—			(5		)
Other	1			—			—			—		(2		)	(1		)
Cost recovery mechanisms – offset in electric revenue^(d)	37			44			—			—		—			81
Total fuel and purchased power change	$	152		$	44		$	—		$	—	$	(2	)	$	194
Net change in electric margins	$	(113	)	$	—		$	—		$	31	$	(5	)	$	(87	)
Natural gas revenue change:
Effect of weather (estimate)^(b)	$	(4	)	$	—		$	—		$	—	$	—		$	(4	)
Base rates (estimate)	—			—			8			—		—			8
QIP rider	—			—			4			—		—			4
Software licensing agreement	—			—			5			—		—			5
Cost recovery mechanisms – offset in natural gas purchased for resale^(d)	8			—			(20		)	—		—			(12		)
Other cost recovery mechanisms^(e)	—			—			2			—		—			2
Total natural gas revenue change	$	4		$	—		$	(1	)	$	—	$	—		$	3
Natural gas purchased for resale change:
Effect of weather (estimate)^(b)	$	4		$	—		$	—		$	—	$	—		$	4
Cost recovery mechanisms – offset in natural gas revenue^(d)	(8		)	—			20			—		—			12
Total natural gas purchased for resale change	$	(4	)	$	—		$	20		$	—	$	—		$	16
Net change in natural gas margins	$	—		$	—		$	19		$	—	$	—		$	19


(a)	Includes an increase in transmission margins of $8$10 millionand$22 million at Ameren Illinois for the three and nine months ended ~~March 31,~~September 30, 2019, compared with the year-ago ~~period.~~periods.


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


(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”,~~“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 increases or decreases to expenses are reflected in “Operating Expenses – Other operations and maintenance” or in “Operating Expenses – Taxes other than income taxes” on the statement of income. These items have no overall impact on earnings.

Ameren

Ameren’s electric margins ~~decreased $6~~increased $7 million, or ~~less than~~ 1%, for the three months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, primarily because of increased margins at Ameren Transmission, as discussed below. Ameren’s electric margins decreased $87 million, or 3%, for the nine months ended September 30, 2019, compared with the year-ago period, primarily because of decreased margins at Ameren Missouri, partially offset by increased margins at Ameren Transmission, ~~and Ameren Illinois Electric Distribution,~~ as discussed below.

Ameren’s natural gas margins ~~increased $22~~decreased $4 million, or ~~12%~~4%, and increased $19 million, or 5%, for the three and nine months ended ~~March 31,~~September 30, 2019, respectively, compared with the year-ago ~~period~~periods, because of ~~increased margins~~margin changes at Ameren Illinois Natural Gas, as discussed below.

Ameren Transmission

Ameren Transmission’s margins increased ~~$10~~$15 million, or 13%, and $31 million, or 10%, for the three and nine months ended ~~March 31,~~September 30, 2019, respectively, compared with the year-ago ~~period.~~periods. Margins were favorably affected by increased capital investment, as evidenced by ~~an 11%~~a 12% increase in rate base used to calculate the revenue requirement.

Ameren Missouri

Ameren Missouri’s electric margins ~~decreased $18 million, or 4%, for~~were comparable between the three months ended ~~March 31,~~September 30, 2019 and 2018. Ameren Missouri’s electric margins decreased $113 million, or 5%, for the nine months ended September 30, 2019, compared with the year-ago period.

The following items had an unfavorable effect on Ameren Missouri’s electric margins for the three and nine months ended September 30, 2019, compared with the year-ago periods (except when a specified period is referenced):

Cooling degree days were comparable between ~~periods:~~the three months ended September 30, 2019 and 2018, but decreased 10% for the nine months ended September 30, 2019. Winter temperatures were warmer as heating degree days decreased 4% for the nine months ended September 30, 2019. The aggregate effect of weather decreased margins an estimated $7 million and $85 million, respectively. The change in margins due to weather is the sum of the effect of weather (estimate) on electric revenues (-$8 million and -$100 million, respectively) and the effect of weather (estimate) on fuel and purchased power (+$1 million and +$15 million, respectively) in the table above.

The reduction of customer rates in accordance with the TCJA provisions in Missouri Senate Bill 564 decreased ~~margins~~revenues an estimated $4 million and $39 million, respectively.

A reduction in power restoration assistance provided to other utilities and the associated recovery of labor and benefit costs for crews supporting those efforts decreased revenues $11 million for the nine months ended September 30, 2019.

Excluding the estimated effects of weather and the MEEIA 2016 and 2019 customer energy-efficiency programs, electric revenues decreased an estimated $6 million for the three months ended September 30, 2019, primarily due to a decrease in the average retail price per kilowatthour due to changes in customer usage patterns, partially offset by increased sales volumes from growth. 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.

Increased transmission services charges resulting from cost-sharing by all MISO participants of additional MISO-approved electric transmission investments made by other entities, which decreased margins $5 million for the nine months ended September 30, 2019.

The following items had a favorable effect on Ameren Missouri’s electric margins for the three and nine months ended September 30, 2019, compared with the year-ago periods (except when a specified period is referenced):

The MEEIA 2013 and MEEIA 2016 performance incentives increased revenues $18 million and $33 ~~million.~~million, respectively. 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.

Excluding the estimated effects of weather and the MEEIA 2016 and 2019 customer energy-efficiency programs, electric revenues increased an estimated $7 million for the nine months ended September 30, 2019, primarily due to an increase in the average retail price per kilowatthour due to changes in customer usage patterns and increased sales volumes from growth. 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.

Net energy costs increased margins $2 million and $3 million, respectively. The change in net energy costs is the sum of the effect of the change in off-system sales (-$50 million and -$101 million, respectively), and the effect of the change in energy costs (+$52 million and +$104 million, respectively) in the table above.

Ameren Missouri’s natural gas margins were comparable between the three and nine months ended September 30, 2019 and 2018.

Ameren Illinois

Ameren Illinois’ electric margins increased $8 million, or 2%, and $22 million, or 2%, for the three and nine months ended September 30, 2019, respectively, compared with the year-ago periods, driven by increased margins at Ameren Illinois Transmission. Ameren Illinois Natural Gas’ margins decreased $4 million, or 4%, and increased $19 million, or 5%, for the three and nine months ended September 30, 2019, respectively, compared with the year-ago periods.

Ameren Illinois Electric Distribution

Ameren Illinois Electric Distribution’s margins were comparable between the three and nine months ended September 30, 2019 and 2018. Ameren Illinois Electric Distribution’s revenues increased $4 million and $11 million for the three and nine months ended September 30, 2019, respectively, compared with the year-ago periods, due to recovery of return on and amortization of increased energy-efficiency program investments pursuant to the FEJA. The following items had an unfavorable effect on Ameren Illinois Electric Distribution’s margins for the three and nine months ended September 30, 2019, compared with the year-ago periods (except when a specified period is referenced):

Revenues decreased due to lower recognized return on equity (-$4 million and -$8 million, respectively, as evidenced by a decrease of nearly 60 basis points in the estimated annual average of the monthly yields of the 30-year United States Treasury bonds) and lower recoverable expenses (-$3 million for the three months ended September 30, 2019), partially offset by an increase in return on rate base (+$1 million and +$6 million, respectively) under formula ratemaking pursuant to the IEIMA. The sum of these changes collectively decreased margins $6 million and $2 million, respectively.

A reduction in power restoration assistance provided to other utilities and the associated recovery of labor and benefit costs for crews supporting those efforts decreased revenues $9 ~~million.~~

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

The MEEIA 2013 and MEEIA 2016 performance incentives increased revenues $15 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.

Winter temperatures were colder as heating degree days increased 2%. The effect of weather increased margins an estimated $2 million. The change in margins due to weather is the sum of the effect of weather (estimate) on electric revenues (+$3 million) and the effect of weather (estimate) on fuel and purchased power (-$1 million) in the table above.

~~Excluding the estimated effects of weather and the MEEIA 2016 customer energy-efficiency programs, total retail sales volumes increased less than 1%, which increased margins an estimated $1~~ million primarily due to growth. The change in margins due to sales volumes is the sum of the effect of sales volumes (excluding the effect of weather) on electric revenues (+$1 million), the effect of the revenue change in off-system sales (-$20 million), and the effect of the change in energy costs (excluding the effect of weather and MEEIA) (+$20 million) in the table above. ~~While MEEIA 2016 customer energy-efficiency programs reduced retail sales volumes, the recovery of lost electric margins ensured that electric margins were not affected.~~

~~Ameren Missouri’s natural gas margins were comparable between periods.~~

~~Ameren Illinois~~

~~Ameren Illinois’ electric margins increased $12 million, or 4%,~~ for the ~~three~~nine months ended March 31, 2019, compared with the year-ago period, driven by increased margins at Ameren Illinois Transmission ($8 million) and Ameren Illinois Electric Distribution ($4 million). Ameren Illinois Natural Gas’ margins increased $22 million between periods.

~~Ameren Illinois Electric Distribution~~

~~Ameren Illinois Electric Distribution’s margins increased $4 million, or 2%, for the three months ended March 31, 2019, compared with the year-ago period.~~

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

Revenues increased due to higher recoverable expenses and increased rate base under formula ratemaking pursuant to the IEIMA, partially offset by a lower recognized return on equity, which collectively increased margins $4 million.

~~Revenues increased $4 million due to energy-efficiency program investments pursuant to the FEJA.~~

Ameren Illinois Electric Distribution’s margins were unfavorably affected by a reduction in power restoration assistance provided to other utilities and the associated recovery of labor and benefit costs for crews supporting those efforts, which decreased revenues $7 million between periods.September 30, 2019.

Ameren Illinois Natural Gas

Ameren Illinois Natural Gas’ margins ~~increased $22~~decreased $4 million, or ~~13%~~4%, and increased $19 million, or 5%, for the three and nine months ended ~~March 31,~~September 30, 2019, respectively, compared with the year-ago ~~period.~~

periods. The following items had a favorable effect on Ameren Illinois Natural Gas’ margins ~~between periods:~~for the three and nine months ended September 30, 2019, compared with the year-ago periods (except when a specified period is referenced):

~~The~~Revenues increased $8 million for the nine months ended September 30, 2019, due to higher natural gas base rates as a result of the November 2018 natural gas rate order.

A software licensing agreement with Ameren Missouri increased revenues $5 million for both periods. See Note 8 – Related-party Transactions under Part I, Item 1, of this report for additional information.


•	Revenues from QIP recoveries, which increased margins $2 millionand$4 million, respectively, due to additional investment in qualified natural gas infrastructure.

Ameren Illinois Natural Gas’ margins were unfavorably affected by the implementation of a change in rate design, ~~pursuant~~which decreased margins $8 million for the three months ended September 30, 2019, compared with the year-ago period. Pursuant to the ICC’s November 2018 natural gas order, ~~increased margins by $12 million. This~~this change in rate design concentrates more revenues in the winter heating season due to an increase in volumetric rates and a decrease in fixed customer rates. The VBA ensures recoverability of the natural gas distribution service revenue requirement for residential and small nonresidential customers that is dependent on sales volumes. As such, the change is not expected to materially affect year-over-year earnings.

~~Revenues increased $6 million due to higher natural gas base rates, as a result of the November 2018 natural gas rate order.~~

Ameren Illinois Transmission

Ameren Illinois Transmission’s margins increased $8$10 million, or ~~13%~~14%, and $22 million, or 11%, for the three and nine months ended ~~March 31,~~September 30, 2019, respectively, compared with the year-ago ~~period.~~periods. Margins were favorably affected by increased capital investment, as evidenced by a ~~15%~~17% increase in rate base used to calculate the revenue requirement.

Other Operations and Maintenance Expenses

Ameren

Other operations and maintenance expenses were ~~$14~~$5 million ~~lower~~and $2 million higher in the three and nine months ended ~~March 31,~~September 30, 2019, respectively, compared with the year-ago ~~period,~~periods, due to ~~the items~~changes discussed below.

Ameren Transmission

Other operations and maintenance expenses were comparable between ~~periods.~~the three months ended September 30, 2019 and 2018. Other operations and maintenance expenses were $4 million lower in the nine months ended September 30, 2019, compared with the year-ago period, primarily due to decreased transmission system maintenance expenditures at Ameren Illinois Transmission.

Ameren Missouri

Other operations and maintenance expenses ~~were~~increased $8 million ~~lower~~ in the three months ended ~~March 31,~~September 30, 2019, compared with the year-ago ~~period. Labor and benefit costs decreased $10 million,~~period, primarily ~~due to a $9 million reduction in power restoration assistance provided to other utilities. Additionally, expenses decreased~~ because of ~~an $8 million increase~~a decrease in the cash surrender value of company-owned life ~~insurance.~~

insurance and increased employee benefit costs. Other operations and maintenance expenses increased $13 million in the nine months ended September 30, 2019, compared with the year-ago period. The following items ~~partially offset the above decreases in~~increased other operations and maintenance expenses ~~between periods:~~for the nine months ended September 30, 2019, compared with the year-ago period:

Energy center operations and maintenance costs increased $5$28 million, primarily due to ~~preparation costs for~~ the Callaway energy center refueling and maintenance outage that ~~began~~was completed in ~~April~~May 2019. The previous Callaway energy center refueling and maintenance outage took place in the fourth quarter of 2017.

~~Electric distribution maintenance expenditures were $4~~Employee benefit costs increased $5 million ~~higher, primarily~~ due to higher medical costs.

The following items partially offset the above increases in other operations and maintenance expenses for the nine months ended September 30, 2019, compared with the year-ago period:

Power restoration assistance provided to other utilities decreased $11 million.

The cash surrender value of company-owned life insurance increased ~~system repair work.~~$7 million.

MEEIA ~~2016~~ customer energy-efficiency program costs ~~increased $3 million.~~decreased $4 million because of higher participation in the MEEIA 2016 programs in 2018, compared with participation in the MEEIA 2019 programs.

Ameren Illinois

Other operations and maintenance expenses were $8comparable between the three months ended September 30, 2019 and 2018. Other operations and maintenance expenses were $10 million lower in the ~~three~~nine months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, ~~at Ameren Illinois,~~ as discussed below. ~~Other operations and maintenance expenses were comparable between periods at Ameren Illinois Natural Gas and Ameren Illinois Transmission.~~

Ameren Illinois Electric Distribution

Other operations and maintenance expenses were $6comparable between the three months ended September 30, 2019 and 2018. Other operations and maintenance expenses were $7 million lower in the ~~three~~nine months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, primarily ~~because of~~due to a ~~decrease in labor and benefit costs resulting from a $7~~$9 million reduction in power restoration assistance provided to other ~~utilities. Additionally, expenses decreased because of~~utilities and a $3 million increase in the cash surrender value of company-owned life insurance. Additionally, expenses decreased due to a $4 million reduction in bad debt costs pursuant to regulatory recovery mechanisms. These decreases were partially offset by a $2$7 million increase in amortization of regulatory assets associated with the FEJA energy-efficiency ~~program.~~program investments.

Ameren Illinois Natural Gas

Other operations and maintenance expenses decreased $4 million in the three months ended September 30, 2019, compared with the year-ago period, primarily due to a reduction in energy efficiency rider costs. Other operations and maintenance expenses were comparable between the nine months ended September 30, 2019 and 2018.

Ameren Illinois Transmission

Other operations and maintenance expenses were comparable between the three months ended September 30, 2019 and 2018. Other operations and maintenance expenses were $3 million lower in the nine months ended September 30, 2019, compared with the year-ago period, primarily due to decreased transmission system maintenance expenditures.

Depreciation and Amortization

Depreciation and amortization expenses increased ~~$14 million, $4~~$7 million and ~~$11~~$8 million in the three months ended ~~March 31,~~September 30, 2019, and $32 million and $26 million in the nine months ended September 30, 2019, compared with the year-ago ~~period,~~periods, at Ameren ~~Ameren Missouri,~~ and Ameren Illinois, respectively, primarily because of additional property, plant, and equipment investments across their respective segments. ~~The increase~~Depreciation and amortization expenses were comparable at Ameren Missouri ~~was partially offset by~~in the three months ended September 30, 2019, with the year-ago period. Depreciation and amortization expenses increased $6 million at Ameren Missouri in the nine months ended September 30, 2019, compared

with the year-ago period, primarily because of additional property, plant, and equipment investments. Ameren Missouri’s depreciation and amortization expenses include a reduction for the regulatory deferral of depreciation ~~expense under~~and amortization expenses pursuant to PISA of ~~$3 million.~~$7 million and $14 million in the three and nine months ended September 30, 2019, respectively.

Taxes Other Than Income Taxes

Taxes other than income taxes ~~were comparable at Ameren~~increased $4 million in the three months ended March 31, 2019, compared with the year-ago period. Taxes other than income taxes decreased $3 million at Ameren Missouri, primarily because of lower gross receipts taxes. Taxes other than income taxes increased $3 million at Ameren Illinois Electric Distribution, primarily because of increased distribution taxes.

~~Other Income, Net~~

~~Other income, net, increased $6 million at Ameren in the three months ended March 31,~~September 30, 2019, compared with the year-ago period, primarily due to an increase in property taxes at Ameren Missouri due to higher assessed values. The increase was partially offset by a decrease in excise taxes at Ameren Missouri as a result of reduced sales, primarily driven by mild summer temperatures. Taxes other than income taxes were comparable between the nine months ended September 30, 2019 and 2018.

Other Income, Net

Other income, net, was comparable between the three months ended September 30, 2019 and 2018. Other income, net, increased $15 million in the nine months ended September 30, 2019, compared with the year-ago period. The non-service cost components of net periodic benefit income atincreased $7 million and $4 million for Ameren Illinois Electric Distribution and ~~Ameren Illinois Natural Gas.~~activity not reported as part of a segment, respectively. Additionally, donations decreased $4 million for activity not reported as part of a segment.

See Note 5 – Other Income, Net under Part I, Item 1, of this report for additional information. See Note 11 – Retirement Benefits under Part I, Item 1, of this report for the non-service cost components of net periodic benefit income.

Interest Charges

Interest charges decreased $5 million and $12 million in the three and nine months ended September 30, 2019, respectively, compared with the year-ago periods. These decreases were primarily due to decreased interest charges at Ameren Missouri, which resulted from lower average interest rates on long-term debt and increased regulatory deferrals of interest expense pursuant to PISA of $4 million and $9 million in the three and nine months ended September 30, 2019, respectively. The decrease at ~~both Ameren and~~ Ameren Missouri in the ~~three~~nine months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, was partially offset by a $4 million increase for activity not reported as part of a segment, primarily because of a ~~lower average~~higher interest rate on ~~long-term debt~~an increased level of short-term borrowings at Ameren Missouri and a deferral of interest expense under PISA of $2 million. Partially offsetting these decreases at Ameren Missouri was an increase in interest charges resulting from higher average outstanding debt. Interest charges were comparable between periods at Ameren Illinois and its segments resulting from a lower average interest rate on long-term debt offset by higher average outstanding debt.(parent).

Income Taxes

The following table presents effective income tax rates for the three and nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Three Months^(a)				Three Months^(a)				Nine Months^(a)
	2019		2018		2019		2018		2019		2018
Ameren	12	%	22	%	20	%	23	%	18	%	23	%
Ameren Missouri	9	%	25	%	14	%	18	%	13	%	21	%
Ameren Illinois	25	%	25	%	24	%	26	%	24	%	25	%
Ameren Illinois Electric Distribution	24	%	22	%	23	%	27	%	23	%	24	%
Ameren Illinois Natural Gas	26	%	26	%	(b)		(b)		26	%	27	%
Ameren Illinois Transmission	25	%	28	%	24	%	22	%	25	%	24	%
Ameren Transmission	26	%	28	%	25	%	22	%	26	%	25	%


(a)	Estimate of the annual effective income tax rate adjusted to reflect the tax effect of items discrete to the three and nine months ended ~~March 31,~~September 30, 2019 and 2018.


(b)	Not meaningful because of the insignificant amount of income before income taxes.

See Note 12 – Income Taxes under Part I, Item 1, of this report for a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the Ameren Companies.

The effective income tax rate was lower at Ameren ~~Transmission and Ameren~~ Illinois ~~Transmission~~Electric Distribution in the three months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, primarily because of increased amortization of excess deferred taxes, higher tax benefits from certain depreciation differences on property-related items largely attributable to the allowance for equity funds used during construction, and the revaluation of certain deferred tax assets and liabilities for provisional amounts related to TCJA in ~~the first quarter of 2019.~~2018. The effective income tax rate was higher at Ameren Illinois ~~Electric Distribution~~Transmission and Ameren Transmission in the three months ended ~~March 31,~~September 30, 2019, compared with the year-ago period, primarily because of lower current year tax benefits from certain depreciation differences on property-related ~~temporary differences~~items largely attributable to the allowance for equity funds used during construction.

LIQUIDITY AND CAPITAL RESOURCES

Collections from our tariff-based revenues are our principal source of cash provided by operating activities. A diversified retail customer mix, primarily consisting of rate-regulated residential, commercial, and industrial customers, provides us with a reasonably predictable source

of cash. In addition to using cash provided by operating activities, we use available cash, borrowings under the Credit Agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, other short-term affiliate borrowings to support normal operations and temporary capital requirements. We may reduce our short-term borrowings with cash provided by operations or, at our discretion, with long-term borrowings or, in the case of Ameren Missouri and Ameren Illinois, with capital contributions from Ameren (parent). In the near term, our operating cash flows will decrease due to the reduction in the federal statutory income tax rate enacted under the TCJA.

The decrease in operating cash flows results from reduced customer rates, reflecting the tax rate decrease, without a corresponding reduction in income tax payments until about 2020 because of our use of net operating losses and tax credit carryforwards. Additionally, operating cash flows will be further reduced by lower customer rates, resulting from the return of excess deferred taxes. Over time, the decrease in operating cash flows will be offset as temporary differences between book and taxable income reverse, and by increased customer rates due to higher rate base amounts resulting from lower accumulated deferred income tax liabilities. We expect to make significant capital expenditures over the next five years as we invest in our electric and natural gas utility infrastructure to support overall system reliability, grid modernization, renewable energy requirements, environmental compliance, and other improvements. 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 2023. Ameren also plans to issue incremental common equity to fund a portion of Ameren Missouri’s wind generation ~~investments.~~investments through the physical settlement of the forward sale agreement relating to 7.5 million shares of common stock. For additional information about the forward sale agreement, see Note 4 – Long-Term Debt and Equity Financings under Part I, Item 1, of this report. Ameren, Ameren Missouri, and Ameren Illinois expect their respective equity to total capitalization levels over the period ending December 2023 to remain in-line with their respective equity to total capitalization levels as of ~~March~~December 31, ~~2019.~~2018.

The use of cash provided by operating activities and short-term borrowings to fund capital expenditures and other long-term investments ~~may periodically result~~at the Ameren Companies frequently results in a working capital deficit, defined as current liabilities exceeding current assets, as was the case at ~~March 31, 2019, for the Ameren Companies.~~September 30, 2019. The working capital deficit as of ~~March 31,~~September 30, 2019, was primarily the result of current maturities of long-term debt and our decision to finance our businesses with lower-cost commercial paper issuances. With the credit capacity available under the Credit Agreements, along with cash and cash equivalents, the Ameren Companies had net available liquidity of ~~$1.3~~$1.6 billion at~~March 31,~~September 30, 2019. See Credit Facility Borrowings and Liquidity below for additional information.

The following table presents net cash provided by (used in) operating, investing, and financing activities for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Net Cash Provided By Operating Activities						Net Cash Used In Investing Activities								Net Cash Provided by Financing Activities							Net Cash Provided By Operating Activities							Net Cash Used In Investing Activities									Net Cash Provided by (Used in) Financing Activities
	2019		2018		Variance		2019			2018			Variance		2019		2018		Variance			2019		2018		Variance			2019			2018			Variance			2019			2018			Variance
Ameren	$	387	$	258	$	129	$	(567	)	$	(597	)	$	30	$	191	$	360	$	(169	)	$	1,668	$	1,686	$	(18	)	$	(1,798	)	$	(1,719	)	$	(79	)	$	178		$	57		$	121
Ameren Missouri	152		76		76		(264		)	(265		)	1		116		192		(76		)	840		961		(121		)	(785		)	(735		)	(50		)	(49		)	(226		)	177
Ameren Illinois	227		130		97		(267		)	(300		)	33		53		181		(128		)	706		516		190			(903		)	(937		)	34			234			451			(217		)

Cash Flows from Operating Activities

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

Ameren

Ameren’s cash from operating activities ~~increased $129~~decreased $18 million in the first ~~three~~nine months of 2019, compared with the year-ago period. The following items contributed to the ~~increase:~~decrease:

A ~~net $36~~$28 million increase in payments for nuclear refueling and maintenance outages at Ameren Missouri’s Callaway energy center. There was no refueling and maintenance outage in 2018.

A $16 million decrease resulting from decreased customer collections, primarily due to ~~the timing of payments of accounts and wages payable.~~

~~A net $26 million increase resulting from costs and associated collections under various cost recovery mechanisms from~~a decrease in weather-related sales volumes at Ameren Missouri, and a net decrease attributable to regulatory recovery mechanisms, partially offset by decreased fuel costs and production volumes at Ameren ~~Illinois customers.~~Missouri and decreased purchase power costs and volumes and natural gas costs at Ameren Illinois.

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

A ~~$24~~$14 million increase resulting from a decrease in coal inventory levels at Ameren Missouri due to delivery disruptions from flooding in 2019.

A ~~$23~~net $14 million increase in collateral received from counterparties, primarily resulting from ~~electric~~changes in the market prices of power and natural gas, ~~margins, as discussed~~changes in ~~Results of Operations, excluding certain noncash items, as well as the change in customer receivable balances.~~

~~The increase in Ameren’s cash~~contracted commodity volumes, and increases resulting from operating activities between periods was partially offset by an $11 million decrease in natural gas held in storage caused primarily by increased withdrawals as a result of colder winter temperatures compared with the year-ago period.

Ameren Illinois’ renewable energy contracts entered into pursuant to FEJA.

Ameren Missouri

Ameren Missouri’s cash from operating activities ~~increased $76~~decreased $121 million in the first ~~three~~nine months of 2019, compared with the year-ago period. The following items contributed to the ~~increase:~~decrease:

A ~~net $25~~$169 million ~~increase~~decrease resulting from decreased customer collections, primarily due to ~~timing of payments of accounts~~a decrease in weather-related sales volumes, and ~~wages payable.~~a net decrease attributable to regulatory recovery mechanisms, partially offset by decreased fuel costs and production volumes.

A ~~$24~~$28 million increase in payments for nuclear refueling and maintenance outages at the Callaway energy center. There was no refueling and maintenance outage in 2018.

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

A $33 million decrease in income tax payments to Ameren (parent) pursuant to the tax allocation agreement, primarily due to lower taxable income in 2019.

A $14 million increase resulting from a decrease in coal inventory levels due to delivery disruptions from flooding in 2019.

A ~~$12~~net $8 million increase in collateral received from counterparties, primarily resulting from changes in the market prices of power and natural gas and in contracted commodity volumes.

Ameren Illinois

Ameren Illinois’ cash from operating activities increased $190 million in the first nine months of 2019, compared with the year-ago period. The following items contributed to the increase:

A $145 million increase primarily resulting from decreased purchased power costs and volumes, decreased natural gas costs, and a net increase attributable to regulatory recovery mechanisms.

A $40 million decrease in income tax payments to Ameren (parent) pursuant to the tax allocation agreement, primarily due to the timing of ~~the~~ payments.

A $6 ~~million increase resulting from electric and natural gas margins, as discussed in Results of Operations, excluding certain noncash items, as well as the change in customer receivable balances.~~

~~A $4 million decrease in interest payments, primarily due to a decrease in the average interest rate of long-term debt.~~

~~A net $3 million decrease in returns of collateral posted with counterparties, primarily resulting from changes in the market prices of power and natural gas and in contracted commodity volumes.~~

The increase in Ameren Missouri’s cash from operating activities between periods was partially offset by a net $24 million decrease resulting from costs and associated collections under various cost recovery mechanisms from customers.

~~Ameren Illinois~~

~~Ameren Illinois’ cash from operating activities increased $97 million in the first three months of 2019, compared with the year-ago period. The following items contributed to the increase:~~

~~A net $50 million increase resulting from costs and associated collections under various cost recovery mechanisms from customers.~~

~~A $22 million decrease in income tax payments to Ameren (parent) pursuant to the tax allocation agreement, primarily due to the timing of the payments.~~

~~A $17 million increase resulting from electric and natural gas margins, as discussed in Results of Operations, excluding certain noncash items, as well as the change in customer receivable balances.~~

~~A $7 million increase related to the timing of net payments to affiliates.~~

~~A $4~~ million decrease in payments to contractors for electric distribution maintenance costs, primarily due to decreased vegetation management costs.

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

~~An $11 million decrease in natural gas held in storage caused primarily by increased withdrawals as a result of colder winter temperatures compared with the prior year.~~

A $7net $6 million increase in ~~interest payments,~~collateral received from counterparties, primarily ~~due to an increase~~resulting from changes in the ~~average outstanding debt.~~market prices of power and natural gas, changes in in contracted commodity volumes, and increases resulting from renewable energy contracts entered into pursuant to FEJA.

Cash Flows from Investing Activities

Ameren’s cash used in investing activities ~~decreased $30~~increased $79 million in the first ~~three~~nine months of 2019, compared with the year-ago period, primarily as a result of ~~decreased~~increased capital expenditures of ~~$35 million, which was driven by activity~~$72 million. In addition to the capital expenditure changes at Ameren Missouri and Ameren Illinois discussed below, Ameren’s capital expenditures increased due to a $30 million increase in capital expenditures at ATXI. ATXI’s capital expenditures increased as ~~discussed below. The decrease was partially~~a result of increased expenditures on the Mark Twain Transmission project offset by ~~a $9 million increase due to~~decreased capital expenditures on the ~~timing of nuclear fuel expenditures.~~Spoon River and Illinois Rivers projects.

Ameren Missouri’s cash used in investing activities ~~was comparable between periods. Nuclear fuel expenditures~~ increased $9$50 million between periods, ~~which was offset by a $9 million decrease~~primarily due to an increase in capital expenditures, partially offset by the absence of net money pool advances in 2019. In the first nine months of 2018, Ameren Missouri made net money pool advances of $28 million. Capital expenditures increased $87 million, primarily due to ~~a reduction in capital expenditures related to software~~substation upgrades and ~~electric distribution system reliability projects.~~energy delivery infrastructure upgrades.

Ameren Illinois’ cash used in investing activities decreased ~~$33~~$34 million between periods primarily due to decreased capital expenditures of $47 million related to ~~substation upgrades, upgrades to natural gas main infrastructure, and~~ electric transmission system reliability projects.

Capital Expenditures

See Liquidity and Capital Resources under Part II, Item 7, of the Form 10-K for Ameren's estimate of capital expenditures that will be incurred from 2019 through 2023, including construction expenditures, allowance for funds used during construction, and expenditures for compliance with existing environmental regulations. Ameren estimates its capital expenditures for 2019 will increase by approximately $150

million to $2,585 million, compared to the estimate included in the Form 10-K, primarily as a result of an increase in capital expenditures at Ameren Missouri of $70 million and Ameren Illinois’ electric transmission business of $85 million.

Cash Flows from Financing Activities

Cash provided by, or used in, financing activities is a result of our financing needs, which depend on the level of cash provided by operating activities, the level of cash used in investing activities, the level of dividends, and our long-term debt maturities, among other things.

Ameren’s cash provided by financing activities ~~decreased $169~~increased $121 million during the first ~~three~~nine months of 2019, compared with the year-ago period. During the first ~~three~~nine months of 2019, Ameren ~~utilized net commercial paper issuances of $202 million and cash on hand to repay long-term indebtedness of $329 million at maturity. Additionally, Ameren~~ issued ~~$450~~$900 million of long-term indebtedness to repay ~~outstanding~~then-outstanding commercial paper issuances, including short-term debt incurred in connection with the repayment at maturity of long-term indebtedness of $329 million. In 2019, Ameren repaid outstanding net commercial paper issuances totaling $53 million, and used cash provided by financing activities to fund, in part, investing activities. In comparison, during the first ~~three~~nine months of 2018, Ameren utilized net proceeds from the issuance of ~~$475~~$889 million of long-term indebtedness and net commercial paper issuances to repay $522 million of higher-cost long-term indebtedness and to fund, in part, investing activities. During the first nine months of 2019, Ameren paid common stock dividends of $350 million, compared with $334 million in dividend payments in the year-ago period.

Ameren Missouri’s cash ~~provided by~~used in financing activities decreased ~~$76~~$177 million during the first ~~three~~nine months of 2019, compared with the year-ago period. During the first ~~three~~nine months of 2019, Ameren Missouri utilized net ~~commercial paper issuances and cash on hand to repay long-term indebtedness~~proceeds from the issuance of ~~$329 million at maturity. Additionally, Ameren Missouri issued~~ $450 million of long-term indebtedness to repay ~~outstanding~~then-outstanding commercial paper ~~and~~issuances, including short-term debt incurred in connection with the repayment at maturity of long-term indebtedness of $329 million. Additionally, Ameren Missouri utilized net commercial paper issuances of $89 million to fund, in part, investing activities. In comparison, during the first ~~three~~nine months of 2018,, Ameren Missouri utilized net proceeds from ~~commercial paper issuances~~the issuance of ~~$243~~$423 million in long-term indebtedness and cash on hand to repay $378 million of higher-cost long-term indebtedness, and to fund, in part, investing activities. ~~Additionally, during~~In 2018, Ameren Missouri also repaid outstanding net commercial paper issuances totaling $39 million. During the first ~~three~~nine months of 2019, Ameren Missouri ~~did not pay~~paid common stock dividends of $250 million, compared with ~~$50~~$225 million in dividend payments in the year-ago period.

Ameren Illinois’ cash provided by financing activities decreased ~~$128~~$217 million during the first ~~three~~nine months of 2019, compared with the year-ago period. During the first ~~three~~nine months of 2019, Ameren Illinois utilized net proceeds from commercial paper issuances of ~~$54~~$237 million to fund, in part, investing activities. In comparison, during the first ~~three~~nine months of 2018, Ameren Illinois utilized net proceeds from the issuance of $476 million of long-term indebtedness and net commercial paper issuances to repay $144 million of ~~$162 million~~higher-cost long-term indebtedness and to fund, in part, investing activities. ~~In the first three months of 2019,~~ Ameren Illinois ~~did not receive a~~also received an $80 million capital contribution from Ameren (parent)~~, compared with a $20~~ and borrowed $45 million ~~capital contribution received~~from the money pool in the year-ago period, compared to no capital contributions or money pool borrowings in the current year period.

See Long-term Debt and Equity in this section for additional information on maturities and issuances of long-term debt.

Credit Facility Borrowings and Liquidity

The liquidity needs of Ameren, Ameren Missouri, and Ameren Illinois are typically supported through the use of available cash, or proceeds from borrowings under the Credit Agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on credit agreements, commercial paper issuances, borrowings under Ameren’s money pool arrangements, and relevant interest rates.

The following table presents Ameren’s consolidated liquidity as of ~~March 31,~~September 30, 2019:


Ameren (parent) and Ameren Missouri:
Missouri Credit Agreement – borrowing capacity	$	1,000	$	1,000
Less: Ameren (parent) commercial paper outstanding	360		53
Less: Ameren Missouri commercial paper outstanding	55		144
Less: Letters of credit	7
Missouri Credit Agreement – subtotal	578		803
Ameren (parent) and Ameren Illinois:
Illinois Credit Agreement – borrowing capacity	1,100		1,100
Less: Ameren (parent) commercial paper outstanding	258		37
Less: Ameren Illinois commercial paper outstanding	126		310
Less: Letters of credit	2		2
Illinois Credit Agreement – subtotal	714		751
Subtotal	$	1,292	$	1,554
Cash and cash equivalents	8		20
Net Available Liquidity	$	1,300	$	1,574

The Credit Agreements are used to borrow cash, to issue letters of credit, and to support issuances under Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper programs. Both Credit Agreements are available to Ameren (parent) to support issuances under Ameren (parent)’s commercial paper program, subject to available credit capacity under the agreements. The Missouri Credit Agreement is available to support issuances under Ameren Missouri’s commercial paper program. The Illinois Credit Agreement is available to support issuances under Ameren Illinois’ commercial paper program. Issuances under the Ameren (parent), Ameren Missouri, and Ameren Illinois commercial paper programs were available at lower interest rates than the interest rates of borrowings under the Credit Agreements. Commercial paper issuances were thus preferred to credit facility borrowings as a source of third-party short-term debt.

In addition, Ameren Missouri and Ameren Illinois may borrow cash from the utility money pool when funds are available. The rate of interest depends on the composition of internal and external funds in the utility money pool. Ameren Missouri and Ameren Illinois will access funds from the utility money pool, the Credit Agreements, or the commercial paper programs depending on which option has the lowest interest rates.

The issuance of short-term debt securities by Ameren’s utility subsidiaries is subject to FERC approval under the Federal Power Act. In 2018, the FERC issued orders authorizing Ameren Missouri and Ameren Illinois to each issue up to $1 billion of short-term debt securities through March 2020 and September 2020, respectively. In ~~2017,~~July 2019, the FERC issued an order authorizing ATXI to issue up to $300 million of short-term debt securities through July ~~2019.~~2021.

The Ameren Companies continually evaluate the adequacy and appropriateness of their liquidity arrangements for changing business

conditions. When business conditions warrant, changes may be made to the Credit Agreements or to other borrowing arrangements.

Long-term Debt and Equity

The following table presents Ameren’s equity issuances, as well as issuances (net of any issuance premiums or discounts), redemptions, repurchases, and maturities of long-term debt for Ameren Missouri, Ameren Illinois, and ATXI for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Month Issued, Redeemed, or Matured	2019			2018			Month Issued, Redeemed, or Matured	2019			2018
Issuances of Long-term Debt
Ameren:
2.50% Senior unsecured notes due 2024								September	$	450		$	—
Ameren Missouri:
3.50% First mortgage bonds due 2029	March	$	450		$	—		March	450			—
4.00% First mortgage bonds due 2048								April	—			423
Ameren Illinois:
3.80% First mortgage bonds due 2028								May	—			430
Total Ameren long-term debt issuances		$	450		$	—			$	900		$	853
Issuances of Common Stock
Ameren:
DRPlus and 401(k)	Various	$	19	^{(a) (b)}	$	17	^{(a) (b)}	Various	$	54	^{(a) (b)}	$	56	^{(a) (b)}
Total common stock issuances		$	19		$	17			$	54		$	56
Total Ameren long-term debt and common stock issuances		$	469		$	17			$	954		$	909
Redemptions and Maturities of Long-term Debt
Ameren Missouri:
6.70% Senior secured notes due 2019	February	$	329		$	—		February	$	329		$	—
6.00% Senior secured notes due 2018								April	—			179
5.10% Senior secured notes due 2018								August	—			199
Ameren Illinois:
6.25% Senior secured notes due 2018								April	—			144
5.70% First mortgage bonds due 2024								September	(c)			—
Total Ameren long-term debt redemptions and maturities		$	329		$	—			$	329		$	522


(a)	Ameren issued a total of ~~0.3~~0.7 million and 0.9 million shares of common stock under its DRPlus and 401(k) plan in ~~both~~ the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and ~~2018.~~2018, respectively.


(b)	Excludes 0.8 million shares of common stock valued at $54 million and 0.7 million shares of common stock valued at $35 million issued in connection with stock-based compensation for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018, respectively.


(c)	Less than $1 million

See Note 4 – Long-Term Debt and Equity Financings under Part 1,I, Item 1, of this report for additional information, including proceeds from issuances of long-term debt, ~~and~~the use of those ~~proceeds.~~proceeds, Ameren’s forward equity sale agreement relating to 7.5 million shares of common stock, and Ameren Illinois’ extinguishment of senior unsecured notes.

Indebtedness Provisions and Other Covenants

See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for a discussion of provisions (and applicable cross-default provisions) and covenants contained in our credit agreements, in ATXI’s note purchase agreement, and in certain of the Ameren Companies’ indentures and articles of incorporation.

At ~~March 31,~~September 30, 2019, the Ameren Companies were in compliance with the provisions and covenants contained in their credit agreements, indentures, and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreement.

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

The amount and timing of dividends payable on Ameren’s common stock are within the sole discretion of Ameren’s board of directors. Ameren’s board of directors has not set specific targets or payout parameters when declaring common stock dividends, but it considers various factors, including Ameren’s overall payout ratio, payout ratios of our peers, projected cash flow and potential future cash flow requirements, historical earnings and cash flow, projected earnings, impacts of regulatory orders or legislation, and other key business considerations. Ameren expects its dividend payout ratio to be between 55% and 70% of annual earnings over the next few years. On ~~May 3,~~October 11, 2019, Ameren’s board of directors declared a quarterly common stock dividend of ~~47.5~~49.5 cents per share payable on ~~June 28,~~December 31, 2019, to shareholders of record on ~~June 12, 2019.~~December 11, 2019, resulting in an annualized equivalent dividend rate of $1.98 per share. The previous annualized equivalent dividend rate, based on the common stock dividend declared and paid in the third quarter of 2019, was $1.90 per share.

See Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for additional discussion of covenants and provisions contained in certain of the Ameren Companies’ financial agreements and articles of

incorporation that would restrict the Ameren Companies’ payment of dividends in certain circumstances. At ~~March 31,~~September 30, 2019, none of these circumstances existed at Ameren, Ameren Missouri, or Ameren Illinois and, as a result, these companies were not restricted from paying dividends.

The following table presents common stock dividends declared and paid by Ameren Corporation to its common shareholders and by Ameren subsidiaries to their parent, Ameren Corporation, for the ~~three~~nine months ended ~~March 31,~~September 30, 2019 and 2018:


	Three Months				Nine Months
	2019		2018		2019		2018
Ameren	$	116	$	111	$	350	$	334
Ameren Missouri	—		50		250		225
ATXI	15		—		15		55

Commitments

For a listing of our obligations and commitments, see Other Obligations in Note 9 – Commitments and Contingencies under Part I, Item 1, of this report. See Note 10 – Retirement Benefits under Part II, Item 8, of the Form 10-K for information regarding expected minimum funding levels for our pension plan.

Off-balance-sheet Arrangements

At ~~March 31,~~September 30, 2019, none of the Ameren Companies had any significant off-balance-sheet financing arrangements, other than variable interest entities, letters of credit, and Ameren (parent) guarantee arrangements on behalf of its subsidiaries. See Note 1 – Summary of Significant Accounting Policies under Part I, Item 1, of this report for further detail concerning variable interest entities.

Credit Ratings

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

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



	Moody’s	S&P
Ameren:
Issuer/corporate credit rating	Baa1	BBB+
Senior unsecured debt	Baa1	BBB
Commercial paper	P-2	A-2
Ameren Missouri:
Issuer/corporate credit rating	Baa1	BBB+
Secured debt	A2	A
Senior unsecured debt	Baa1	Not Rated
Commercial paper	P-2	A-2
Ameren Illinois:
Issuer/corporate credit rating	A3	BBB+
Secured debt	A1	A
Senior unsecured debt	A3	BBB+
Commercial paper	P-2	A-2
ATXI:
Issuer credit rating	A2	Not Rated
Senior unsecured debt	A2	Not Rated

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

Collateral Postings

Any weakening of our credit ratings may reduce access to capital and trigger additional collateral postings and prepayments. Such changes may also increase the cost of borrowing, resulting in an adverse effect on earnings. Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts, and cash collateral posted by external parties were immaterial at ~~March 31,~~September 30, 2019. A sub-investment-grade issuer or senior unsecured debt rating (below “Baa3” from Moody’s or below “BBB-” from S&P) at ~~March 31,~~September 30, 2019, 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 ~~$87~~$155 million, ~~$58~~$119 million, and ~~$29~~$36 million, respectively.

Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at ~~March 31,~~September 30, 2019, if market prices were 15% higher or lower than ~~March 31,~~September 30, 2019 levels in the next 12 months and 20% higher or lower thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, or Ameren Illinois could be required to post an immaterial amount, compared to each company’s liquidity, of collateral or other assurances for certain trade obligations.

OUTLOOK

We seek to earn competitive returns on investments in our businesses. We seek to improve our regulatory frameworks and cost recovery mechanisms and are simultaneously pursuing constructive regulatory outcomes within existing frameworks, while also advocating for responsible energy policies. We align our overall spending, both operating and capital, with economic conditions and with the frameworks established by our regulators to create and capitalize on investment opportunities for the benefit of our customers and shareholders. We focus on minimizing the gap between allowed and earned returns on equity and on allocating capital resources to business opportunities that we expect will offer the most attractive risk-adjusted return potential.

As part of Ameren’s strategic plan, we pursue projects to meet our customers’ energy needs and to improve electric and natural gas system reliability, safety, and security within our service territories. Ameren also evaluates competitive electric transmission investment

opportunities as they arise. Additionally, Ameren Missouri expects to transition to a cleaner, more diverse energy generation portfolio over time by making investments in renewable energy resources and retiring its coal-fired generation at the end of each energy center’s useful life, among other things.

Below are some key trends, events, and uncertainties that may reasonably affect our results of operations, financial condition, or liquidity, as well as our ability to achieve strategic and financial objectives, for 2019 and beyond.

Operations

In 2018, Missouri Senate Bill 564 was enacted and Ameren Missouri elected PISA in accordance with the provisions of the law. Pursuant to its PISA election, Ameren Missouri is permitted to defer and recover 85% of the depreciation expense and a weighted-average cost of capital return on rate base on certain property, plant, and equipment placed in service after September 1, 2018, and not included in base rates. Accumulated PISA deferrals earn carrying costs at the weighted-average cost of capital, and all approved PISA deferrals will be added to rate base prospectively and recovered over a period of 20 years following a regulatory rate review. PISA mitigates the impacts of regulatory lag between regulatory rate reviews. The remaining 15% of depreciation expense for certain property, plant, and equipment placed in service and not eligible for recovery under PISA remains subject to regulatory lag, unless eligible for recovery under the RESRAM. As a result of the PISA election, additional provisions of the law apply to Ameren Missouri, including limitations on electric customer rate increases and an electric base rate freeze until April 2020. 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. In January 2019, the MoOPC filed an appeal with the Missouri Court of Appeals, Western District, challenging the MoPSC’s December 2018 order allowing Ameren Missouri to recover, through the RESRAM, the ~~15%~~ of depreciation expense and weighted average cost of capital return not recovered under PISA. Ameren Missouri expects a decision by the end of 2019. The RESRAM is designed to mitigate the impacts of regulatory lag for the cost of compliance with renewable energy standards, including recovery of investments in wind and other renewable generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA.

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In 2018, Missouri Senate Bill 564 was enacted and Ameren Missouri elected PISA in accordance with the provisions of the law. Pursuant to its PISA election, Ameren Missouri is permitted to defer and recover 85% of the depreciation expense and a weighted average cost of capital return on rate base on certain property, plant, and equipment placed in service after September 1, 2018, and not included in base rates. Accumulated PISA deferrals earn carrying costs at the weighted-average cost of capital, 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 weighted-average cost of capital return for renewable generation plant placed in service and not recovered under PISA. Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. PISA and the RESRAM mitigate the effects of regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under 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 weighted average cost of capital, both debt and equity, which will ultimately be recognized in revenues when recovery of such deferrals are 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 and an electric base rate freeze until April 2020. 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. In January 2019, the MoOPC filed an appeal with the Missouri Court of Appeals, Western District, challenging the MoPSC’s December 2018 order allowing Ameren Missouri to recover, through the RESRAM, the 15% of depreciation expense and weighted average cost of capital return not recovered under PISA. In October 2019, the Missouri Court of Appeals, Western District upheld the MoPSC’s order. In November 2019, the MoOPC filed a request for appeal of the MoPSC’s order to the Missouri Supreme Court. The RESRAM is designed to mitigate the impacts of regulatory lag for the cost of compliance with renewable energy standards, including recovery of investments in wind and other renewable energy generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA.

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In February 2019, Ameren Missouri announced its Smart Energy Plan, which includes a five-year capital investment overview with a detailed one-year plan for 2019. 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 $6.3 billion over the five-year period from 2019 through 2023, with expenditures largely recoverable under PISA and the RESRAM.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 the end of 2020.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.

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 regulatory recovery 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, including $30 million if 100% of~~goals. If the target goals are achieved ~~during the period ending December 2021. Additional~~for 2019, 2020, and 2021, 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, respectively, if Ameren Missouri exceeds ~~100% of~~ its targeted energy savings goals. Ameren Missouri recognized $28 million, $11 million, and $38 million in revenues related to MEEIA performance incentives in 2017, 2018, and during the nine months ended September 30, 2019, respectively.

In ~~May 2019,~~June 2018, the MoPSC approved Ameren Missouri’s Renewable Choice Program, which allows large commercial and industrial customers and municipalities to elect to receive up to 100% of their energy from renewable resources. The tariff-based program is designed to recover the costs of the election, which includes a return on any generation owned by Ameren Missouri. Based on customer

contracts, the program enables Ameren Missouri ~~provided notice~~to supply up to 400 megawatts of renewable wind energy generation, up to 200 megawatts of which it could own. As applicable, the addition of generation by Ameren Missouri would be subject to the issuance of a certificate of convenience and necessity by the MoPSC, ~~that it plans~~obtaining transmission interconnection agreements with MISO or other RTOs, and FERC approval. Any owned generation under this program would be incremental to ~~file for an electric service regulatory rate review, which it intends to file as early as July 2019.~~estimated capital expenditures through 2023 discussed below. Ameren Missouri ~~expects key drivers of~~anticipates finalizing customer interest and pursuing renewable energy projects to fulfill requirements in 2020. Ameren Missouri-owned generation associated with this ~~rate review to include increased infrastructure investments and other costs of service. Additionally, lower coal and transportation expenses are~~program, if any, is not expected to be ~~incorporated~~placed into ~~base rates. Electric base rates were last reset on April 1, 2017, and are required~~service before 2021. Without extension, the option to ~~be reset at least every four years to allow for continued use of~~elect into the ~~fuel adjustments clause.~~

Ameren continues to make significant investments in FERC-regulated electric transmission businesses. Ameren Illinois expects to invest $2.2 billion in electric transmission assets from 2019 through 2023, to replace aging infrastructure and improve reliability. ATXI has three MISO-approved multi-value projects: the Spoon River, Illinois Rivers, and Mark Twain projects. The Spoon River project, located in northwest Illinois, was placed in service in February 2018. The Illinois Rivers project involves the construction of a transmission line from eastern Missouri across Illinois to western Indiana. Construction of the Illinois Rivers project is substantially complete, with the last section expected to be complete in 2020, pending the outcome of certain legal proceedings. The Mark Twain project involves the construction of a transmission line from northeast Missouri, connecting the Illinois Rivers project to Iowa. Construction of the Mark Twain project beganprogram will terminate in the ~~second~~third quarter of 2018, and is expected to be completed by the end of 2019. ATXI’s expected remaining investment in its multi-value projects is approximately $200 million, with the total investment expected to be more than $1.6 billion.2023.

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In July 2019, Ameren Missouri filed a request with the MoPSC seeking approval to decrease its annual revenues for electric service by $1 million. The electric rate decrease request is based on a9.95%return on common equity, a capital structure composed of51.9% common equity, a rate base of $8.0 billion, and a test year ended December 31, 2018, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2019. Pro-forma adjustments are also expected for fuel costs, transportation costs, MISO multi-value transmission project expenses, and payroll costs effective as of January 1, 2020.The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by late April 2020 and new rates effective by late May 2020. A 50 basis point change in Ameren Missouri’s return on common equity would result in an estimated $20 million change in Ameren’s and Ameren Missouri’s net income, based on Ameren Missouri’s current electric rate base.

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Ameren continues to make significant investments in FERC-regulated electric transmission businesses. Ameren Illinois expects to invest $2.2 billion in electric transmission assets from 2019 through 2023, to replace aging infrastructure and improve reliability. ATXI is developing two MISO-approved multi-value projects: the Illinois Rivers and Mark Twain projects. The Illinois Rivers project involves the construction of a transmission line from eastern Missouri across Illinois to western Indiana. Construction of the Illinois Rivers project is substantially complete, with the last section expected to be completed in 2020. The Mark Twain project involves the construction of a transmission line from northeast Missouri, connecting the Illinois Rivers project to Iowa. Construction of the Mark Twain project began in the second quarter of 2018. In June 2019, the first section of the Mark Twain project was completed from Kirksville, Missouri to the Iowa border, and the remaining section is expected to be completed by the end of 2019. ATXI’s expected investment in 2019 and 2020 to complete its multi-value projects is approximately $200 million, with the total investment expected to be more than $1.6 billion.

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 10.82% return on common equity, the ~~2019~~ revenue requirements that will be included in 2020 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are ~~$297~~$317 million and ~~$177~~$195 million, respectively. These revenue requirements represent an increase in Ameren Illinois' and ATXI’s revenue requirements of ~~$24~~$20 million and $3$18 million, respectively, from the revenue requirements reflected in 2019 rates, primarily due to the expected rate base growth. These rates will affect Ameren Illinois’ and ATXI’s cash receipts during ~~2019,~~2020, but will not determine their respective electric transmission service operating revenues, which will instead be based on ~~2019~~2020 actual recoverable costs, rate base, and return on common equity as calculated under the FERC formula ratemaking framework.

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The return on common equity for MISO transmission owners, including Ameren Illinois and ATXI, is the subject of a FERC complaint case filed in February 2015 challenging the allowed base return on common equity. Ameren Illinois and ATXI currently use the FERC authorized total allowed return on common equity of 10.82% in customer rates. A final FERC order would establish the allowed return on common equity to be applied to the 15-month period from February 2015 to May 2016 and also establish the return on common equity to be included in customer rates prospectively from the effective date of such order, replacing the current 10.82% total return on common equity. In October 2018, the FERC issued an order in an unrelated case that proposed a new methodology for determining the base return on equity, which required further briefs from the participants. In November 2018, the FERC issued an order related to the February 2015 complaint case and the September 2016 order, which required participants to file briefs in February 2019 regarding the FERC’s proposed methodology for determining the base return on common equity, including whether and how to apply the proposed methodology to the two MISO complaint cases. In March 2019, the FERC issued separate Notices of Inquiry regarding its allowed base return on common equity 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 return on common equity 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 return on common equity. Ameren is unable to predict the ultimate impact of the proposed methodology on these complaint cases

The return on common equity for MISO transmission owners, including Ameren Illinois and ATXI, is the subject of a FERC complaint case filed in February 2015 challenging the allowed base return on common equity. Ameren Illinois and ATXI currently use the FERC authorized total allowed return on common equity of 10.82% in customer rates. A final FERC order would establish the allowed return on common equity to be applied to the 15-month period from February 2015 to May 2016 and also establish the return on common equity to be included in customer rates prospectively from the effective date of such order, replacing the current 10.82% total return on common equity. In October 2018, the FERC issued an order in an unrelated case that proposed a new methodology for determining the base return on equity and required further briefs from the participants. In November 2018, the FERC issued an order related to the February 2015 complaint case and the September 2016 order, which required participants to file briefs in February 2019 regarding the FERC’s proposed methodology for determining the base return on common equity, including whether and how to apply the proposed methodology to the two MISO complaint cases. In March 2019, the FERC issued separate Notices of Inquiry regarding its allowed base return on common equity policy and its transmission incentives policy, with comments due in June 2019. The Notice of Inquiry addressing the FERC’s return on common equity policy, among other things, broadens the ability to comment on the new methodology beyond electric utilities that are participants in the complaint cases, and the transmission incentives Notice of Inquiry is open for industry comment on the FERC’s transmission incentive policy, including incentive adders to the return on common equity. Ameren is unable to predict the ultimate impact of the proposed methodology on these complaint cases

or the Notices of Inquiry at this time.As the FERC is under no deadline to issue a final order, the timing of the final order in the February 2015 complaint case and any potential impact to the amounts refunded as a result of the September 2016 order is uncertain. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for more information regarding FERC complaint cases. A 50 basis point reduction in the FERC-allowed base return on common equity would reduce Ameren’s and Ameren Illinois’ net income by an estimated $9 million and $5 million, respectively, based on each company’s 2019 projected rate base.

In 2018, the ICC issued an order in Ameren Illinois’ annual update filing that approved a $72 million increase in Ameren Illinois’ electric distribution service rates beginning in January 2019. Illinois law provides for an annual reconciliation of the electric distribution revenue requirement as is necessary to reflect the actual costs incurred and investment return in a given year with the revenue requirement that was reflected in customer rates for that year. Unless extended, the formula ratemaking framework expires at the end of 2022, while the decoupling provisions extend beyond the end of the formula ratemaking by law. Consequently, Ameren Illinois’ 2019 electric distribution service revenues will be based on its 2019 actual recoverable costs, rate base, and return on common equity as calculated under the Illinois performance-based formula ratemaking framework. The 2019 revenue requirement ~~is expected to be higher than the 2018 revenue requirement because of an expected increase in recoverable costs and expected rate base growth of approximately 8%. The 2019 revenue requirement~~

reconciliation is expected to result in a regulatory asset that will be collected from customers in 2021. 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 $8 million change in Ameren’s and Ameren Illinois’ net income, based on Ameren Illinois’ 2019 projected year-end rate base.

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Ameren Illinois ~~filed its annual electric distribution~~expects to file for a natural gas delivery service ~~formula~~regulatory rate ~~update to establish the revenue requirement to be used for~~review in early 2020 ~~rates~~ with ~~the ICC. Pending ICC approval, this update filing will result in~~ a ~~$7 million~~ ~~decrease in~~ future test year ended December 31, 2021. Ameren Illinois’ ~~electric distribution~~current allowed return on equity for natural gas delivery service ~~rates, beginning in January 2020.~~ ~~These rates will affect Ameren Illinois' cash receipts during 2020 but will not affect electric distribution service revenues, which will be based on actual recoverable costs,~~is 9.87%, with a capital structure composed of 50% common equity, a rate base of $1.6 billion, and ~~return on common equity as calculated under the Illinois performance-based formula ratemaking framework.~~

a 2019 future test year.

Ameren Illinois is allowed to earn a return on its electric energy-efficiency program investments. Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at its weighted-average cost of capital, with the equity return based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The equity portion of Ameren Illinois’ return 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. Pursuant to the FEJA, Ameren Illinois plans to invest up to approximately $100 million per year in electric energy-efficiency programs through 2023, and will earn a return on those investments. The ICC has the ability to reduce electric energy-efficiency savings goals if there are insufficient cost-effective programs available or if the savings goals would require investment levels that exceed amounts allowed by legislation. 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 formula ratemaking framework.

Ameren Missouri's scheduled refueling and maintenance outage at its Callaway energy center began in April 2019. Ameren Missouri expects to incur $34 million in maintenance expenses in 2019 related to the outage. 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, which results in limited impacts to earnings. Ameren Missouri’s next refueling and maintenance outage at its Callaway energy center is scheduled for the fall of 2020.

•

Ameren Missouri's next refueling and maintenance outage at its Callaway energy center is scheduled for the fall of 2020. 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, which results in limited impacts to earnings. In October 2019, Ameren Missouri filed a request with the MoPSC for deferral accounting treatment that would allow Ameren Missouri to defer and amortize maintenance expenses related to scheduled refueling and maintenance outages at its Callaway nuclear energy center. These expenses would be amortized over the period between refueling and maintenance outages, which is approximately 18 months. Ameren Missouri cannot predict the ultimate outcome of this regulatory proceeding. If the request is approved prior to the fall 2020 refueling and maintenance outage, Ameren Missouri would defer the maintenance expenses incurred related to the outage as a regulatory asset and begin to amortize those expenses after completion of the outage.

•

Ameren Missouri and Ameren Illinois continue to make infrastructure investments and expect to seek regular electric and natural gas rate increases to recover the cost of investments and earn an adequate return. Ameren Missouri and Ameren Illinois will also seek legislative solutions, as necessary, 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, 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 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.

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.

For additional information regarding recent rate orders, lawsuits, and pending requests filed with state and federal regulatory commissions, see Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K.

Liquidity and Capital Resources

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 at least 700 megawatts of wind generation by the end of 2020 in Missouri and neighboring states 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: 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; Ameren Missouri’s ability to obtain timely interconnection agreements with MISO or other RTOs, as well as the cost of such interconnections; and Ameren Missouri’s ability to obtain a certificate of convenience and necessity from the MoPSC, and any other required project approvals.

•

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 at least 700 megawatts of wind generation by the end of 2020 in Missouri and neighboring states 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: 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; Ameren Missouri’s ability to obtain timely interconnection agreements with MISO or other RTOs at an acceptable cost; and Ameren Missouri’s ability to obtain a certificate of convenience and necessity from the MoPSC, and any other required project approvals. Ameren Missouri expects to file its next IRP in September 2020.

•

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 center’s useful life. The Meramec, Sioux, Labadie, and Rush Island energy centers are expected to be retired in 2022, 2033, 2042, and 2045, respectively. As of December 31, 2018, rate base at Ameren Missouri’s coal-fired energy centers was approximately $0.8 billion, $0.6 billion, $0.4 billion, and $0.2 billion for the Labadie, Sioux, Rush Island, and Meramec energy centers, respectively.

~~level. Ameren Missouri is also targeting a 35% CO~~₂ 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 center’s useful life.

~~In May 2019, Ameren Missouri entered into a build-transfer agreement with a subsidiary of Enel Green Power North America, Inc. to acquire, after construction, an up-to~~ ~~300-~~megawatt wind generation facility to be located in northwestern Missouri. Ameren Missouri expects to file for a certificate of convenience and necessity with the MoPSC in May 2019. Final RTO interconnection costs are expected to be determined in June 2019, and a related RTO transmission interconnection agreement is expected in the fall of 2019.

~~In 2018, Ameren Missouri entered into two build-transfer agreements to acquire, after construction, an up-to~~ ~~400-megawatt wind generation facility and an up-to~~ ~~157-~~megawatt wind generation facility. In October 2018, the MoPSC issued an order approving a unanimous stipulation and agreement regarding a requested certificate of convenience and necessity for the up-to 400-megawatt facility. In March 2019, the MoPSC issued an order approving a nonunanimous stipulation and agreement regarding a requested certificate of convenience and necessity for the up-to 157-megawatt facility. Final MISO interconnection costs for the up-to 400-megawatt facility are expected to be determined in June 2019, and a related transmission interconnection agreement with the MISO is expected in the fall of 2019. Final MISO interconnection costs for the up-to 157-megawatt facility are expected to be determined in the fall of 2019, and a related transmission interconnection agreement with the MISO is expected in early 2020.

All three facilities are expected to be completed by the end of 2020, which would support Ameren Missouri’s compliance with the Missouri renewable energy standard. Each acquisition is subject to certain conditions, including the issuance of a certificate of convenience and necessity by the MoPSC for the up-to 300-megawatt facility, obtaining FERC approval for the up-to 157-megawatt facility and the up-to 300-megawatt facility, entering into an RTO transmission interconnection agreement at an acceptable cost for each facility, and other customary contract terms and conditions.~~The three build-transfer agreements collectively represent approximately~~ ~~$1.4 billion~~ ~~of capital expenditures expected in 2020.~~The MoPSC has approved a RESRAM, which is designed to mitigate the impacts of regulatory lag for the cost of compliance with renewable energy standards, including recovery of investments in wind and other renewable generation, by providing more timely recovery of costs and a return on investments not already provided for in customer rates or recovered under PISA.

•

In May 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-to400-megawatt wind generation facility.The two build-transfer agreements, which are subject to customary contract terms and conditions, collectively represent approximately $1.2 billion of capital expenditures, are expected to be completed by the end of 2020, 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.The county zoning approval process for the Schuyler County portion of the 400-megawatt project is subject to litigation filed in August 2019, which is not expected to affect the completion of the project by the end of 2020.See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for more information regarding Ameren Missouri wind generation facilities.

Through 2023, 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 $13.9 billion (Ameren Missouri – up to $7.1 billion; Ameren Illinois – up to $6.6 billion; ATXI – up to $0.2 billion) of capital expenditures during the period from 2019 through 2023. Ameren’s and Ameren Missouri’s estimates include approximately $1 billion in 2020 for capital investment in wind generation ~~facilities.~~facilities and 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.

•

Environmental regulations, including those related to CO₂emissions, 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 ~~proposed~~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.

•

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 4 – Long-Term Debt and Equity Financings under Part I, Item 1, of this report for additional information.

The Ameren Companies have multiyear credit agreements that cumulatively provide $2.1 billion of credit through December 2022, 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 $2.5 billion. The Ameren Companies expect to amend and extend these credit agreements in the fourth quarter of 2019. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information regarding the Credit Agreements. Ameren Illinois expects to issue long-term debt in the fourth quarter of 2019. 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.

Ameren expects its cash used for currently planned capital expenditures and dividends to exceed cash provided by operating activities over the next several years. To fund a portion of these cash requirements, beginning in 2018, Ameren began using newly issued shares of common stock, rather than market-purchased shares, to satisfy requirements under its DRPlus and employee benefit plans and expects to continue to do so over the next five years. Ameren also plans to issue incremental common equity to fund a portion of Ameren Missouri’s wind generation investments through the settlement of the forward sale agreement discussed above. Ameren, Ameren Missouri, and Ameren Illinois expect their respective equity to total capitalization levels over the period ending December 2023 to remain in-line with their respective equity to total capitalization levels as of December 31, 2018. Ameren Missouri and Ameren Illinois expect to fund cash flow needs through debt issuances, adjustments of dividends to Ameren (parent), and/or capital contributions from Ameren (parent).

Federal income tax legislation enacted under the TCJA will continue to have significant impacts on our results of operations, financial position, liquidity, and financial metrics. The TCJA, among other things, reduced the federal statutory corporate income tax rate from 35% to 21%, effective January 1, 2018. Customer rates were reduced to reflect the lower income tax rate, without a corresponding reduction in income tax payments because of our use of net operating losses and tax credit carryforwards until about 2020. Customer rates were also reduced to reflect the return of excess deferred taxes. The result of these customer rate reductions is a decrease in

operating cash flows in the near term. Over time, the decrease in operating cash flows will be offset as temporary differences between book and taxable income reverse, and by increased customer rates due to higher rate base amounts resulting from lower accumulated deferred income tax liabilities.

In 2018, our rate-regulated businesses began to amortize excess deferred taxes. Ameren ~~Illinois~~Illinois’ and ATXI's income tax expense for the year ended December 31, 2018, reflect a full year of amortization, while Ameren Missouri's income tax expense for the year ended December 31, 2018, reflects five months of amortization related to its electric business, in accordance with a MoPSC order received in July 2018. The amortization of such balances related to Ameren Missouri’s gas business started in January 2019, in accordance with a MoPSC order received in December 2018. These amortizations reduce our income tax expense and effective tax rates. Due to formula ratemaking, Ameren Illinois Electric Distribution and Ameren Transmission have an offsetting reduction in revenue from customers, with no overall impact on earnings. Ameren Missouri and Ameren Illinois Natural Gas ~~2019~~ interim period earnings comparisons between 2019 and 2018 may be affected by timing differences between income tax expense and revenue reductions based on their revenue patterns; however, no material impact to year-over-year earnings is expected.

As of ~~March 31,~~September 30, 2019, Ameren had ~~$99~~$88 million in tax benefits ~~from federal and state net operating loss carryforwards and $128 million in~~related to federal and state income tax credit carryforwards. ~~These carryforwards are expected to largely offset income~~Ameren has utilized all tax ~~obligations in 2019. The~~benefits from net operating loss ~~carryforwards are~~carryforwards. Future expected ~~to be fully utilized in 2019. Ameren does not expect to make material federal or state~~ income tax payments ~~over the next five years~~and refunds are based on planned capital expenditures and any related income tax ~~credits. Consistent~~credits and, in the case of Ameren Missouri and Ameren Illinois, consistent with the tax allocation agreement between Ameren (parent) and its ~~subsidiaries,~~subsidiaries. Ameren expects to make income tax payments between $10 million and $50 million in each year from 2019 to 2023, totaling $135 million to $185 million for the five-year period. Ameren Missouri expects to make ~~material~~ income tax payments to Ameren (parent) of approximately $110 million in 2019 and ~~2020~~between $20 million and ~~immaterial payments~~$30 million in 2020. Additionally, Ameren Missouri expects to receive refunds from Ameren (parent) in each year from 2021 ~~through~~to 2023, ~~based on planned capital expenditures and related income tax credits, while~~totaling $30 million to $60 million for the three-year period. Ameren Illinois expects to make ~~material~~ income tax payments to Ameren (parent) between $10 million and $40 million in 2019 ~~through 2023.~~

~~Ameren expects its cash used~~and 2020 and between $50 million and $70 million in each year from 2021 to 2023, totaling $200 million to $250 million for ~~currently planned capital expenditures and dividends to exceed cash provided by operating activities over~~ the next several years. To fund a portion of these cash requirements, beginning in 2018, Ameren began using newly issued shares of common stock, rather than market-purchased shares, to satisfy requirements under its DRPlus and employee benefit plans and expects to continue to do so over the next five years. Ameren also plans to issue incremental common equity to fund a portion of Ameren Missouri’s wind generation investments. Ameren, Ameren Missouri, and Ameren Illinois expect their respective equity to total capitalization levels over the period ending December 2023 to remain in-line with their respective equity to total capitalization levels as of December 31, 2018. Ameren Missouri and Ameren Illinois expect to fund cash flow needs through debt issuances, adjustments of dividends to Ameren (parent), and/or capital contributions from Ameren (parent).five-year period.

The above items could have a material impact on our results of operations, financial position, and liquidity. Additionally, in the ordinary course of business, we evaluate strategies to enhance our results of operations, financial position, and liquidity. These strategies may include

acquisitions, divestitures, opportunities to reduce costs or increase revenues, and other strategic initiatives to increase Ameren’s shareholder value. We are unable to predict which, if any, of these initiatives will be executed. The execution of these initiatives may have a material impact on our future results of operations, financial position, or liquidity.

REGULATORY MATTERS

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

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

Commodity Supplier and Price Risk

In 2019, two of Ameren Missouri’s ultra-low-sulfur coal suppliers filed voluntary petitions for restructuring under Chapter 11 of the United States Bankruptcy Code. Ameren Missouri expects to replace any resulting volume shortfall through its other coal supply contracts or through market purchases. As of September 30, 2019, forward market prices for coal were comparable to Ameren Missouri’s contracted prices with these two suppliers. As such, Ameren Missouri does not expect any material impact to its operations as a result of these restructuring proceedings.

ITEM 4. CONTROLS AND PROCEDURES.


(a)	Evaluation of Disclosure Controls and Procedures

As of ~~March 31,~~September 30, 2019, evaluations were performed under the supervision and with the participation of management, including the principal executive officer and the principal financial officer of each of the Ameren Companies, of the effectiveness of the design and operation of such registrant’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act). Based on those evaluations, as of ~~March 31,~~September 30, 2019, the principal executive officer and the principal financial officer of each of the Ameren Companies concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in such registrant’s reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to its management, including its principal executive officer and its principal financial officer, to allow timely decisions regarding required disclosure.


(b)	Changes in Internal Controls over Financial Reporting

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

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS.

We are involved in legal and administrative proceedings before various courts and agencies with respect to matters that arise in the ordinary course of business, some of which involve substantial amounts of money. We believe that the final disposition of these proceedings, except as otherwise disclosed in this report, will not have a material adverse effect on our results of operations, financial position, or liquidity. Risk of loss is mitigated, in some cases, by insurance or contractual or statutory indemnification. Material legal and administrative proceedings, which are discussed in Note 2 – Rate and Regulatory Matters, Note 9 – Commitments and Contingencies, and Note 10 – Callaway Energy Center, under Part I, Item 1, of this report include the following:

Ameren Missouri’s electric service regulatory rate review filed with the MoPSC in July 2019;

the November 2019 request filed by the MoOPC to appeal the MoPSC’s December 2018 order in the RESRAM case to the Missouri Supreme Court;

Ameren Missouri’s request for deferral accounting treatment of maintenance expenses related to scheduled Callaway refueling and maintenance outages filed with the MoPSC in October 2019;

Ameren Illinois’ annual electric distribution service formula rate update filed with the ICC in April 2019;

Ameren ~~Missouri’s natural gas delivery service regulatory~~Illinois’ annual electric energy-efficiency formula rate ~~review~~update filed with the ~~MoPSC~~ICC in ~~December 2018;~~May 2019;

the February 2015 complaint case filed with the FERC seeking a reduction in the allowed base return on common equity under the MISO tariff;

the November 2018 FERC order requesting briefs regarding a new methodology for determining the base return on common equity under the MISO tariff and how to apply the new methodology to the February 2015 complaint case and the September 2016 order related to the November 2015 complaint case;

the March 2019 FERC separate Notices of Inquiry regarding its allowed base return on common equity policy and its transmission incentives policy;

~~the January 2019 appeal filed by the MoOPC challenging the MoPSC’s December 2018 order in the RESRAM case;~~

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

remediation matters associated with former MGP sites of Ameren Illinois.

ITEM 1A. RISK FACTORS.

There have been no material changes to the risk factors disclosed in Part I, Item 1A, Risk Factors in the Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.

Ameren Corporation, Ameren Missouri, and Ameren Illinois did not purchase equity securities reportable under Item 703 of Regulation S-K during the period from ~~January~~July 1, 2019, to ~~March 31,~~September 30, 2019.

ITEM 6. EXHIBITS.

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



Exhibit Designation	Registrant(s)	Nature of Exhibit	Previously Filed as Exhibit to:
Instruments Defining Rights of Security Holders, Including Indentures
4.1	Ameren	Ameren Indenture Company Order, dated September 16, 2019, establishing the 2.50% Senior Notes due 2024(including the global note)	September 16, 2019 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756
4.2	Ameren Ameren ~~Missouri~~ Illinois	Third Supplemental Indenture to the CILCO Indenture, dated as of October 15, 2019, amending the CILCO Indenture
4.3	Ameren Ameren Illinois	Supplemental Indenture, dated as of October 15, 2019, to Ameren Illinois Mortgage for First Mortgage Bonds, Senior Notes Series CILCO-AA
4.4	Ameren Ameren Illinois	Fourth Supplemental Indenture to the Ameren ~~Missouri Mortgage,~~Illinois Indenture, dated ~~March 1,~~as of October 15, 2019 ~~for 3.50% First Mortgage Bonds due 2029~~	~~March 6,~~
4.5	Ameren Ameren Illinois	Ameren Illinois Indenture Company Order, dated October 30, 2019, ~~Form 8-K, Exhibit 4.2 File No. 1-2967~~establishing Senior Notes Series CILCO-AA
4.6	Ameren Ameren Illinois	Global Senior Note Series CILCO-AA
Material Contracts
10.1	Ameren ~~Illinois~~	~~Sign On~~Forward Sale Agreement, dated August 5, 2019, between Ameren and ~~Retention Bonus Agreement, effective March 1, 2018, between Bhavani Amirthalingam~~Goldman Sachs & Co. LLC, as the Forward Purchaser	August 7, 2019 Form 8-K, Exhibit 10 File No. 1-14756
10.2	Ameren Companies	Revised Schedule I to Second Amended and Restated Ameren ~~Services Company~~Change of Control Severance Plan, as amended
Rule 13a-14(a) / 15d-14(a) Certifications
31.1	Ameren	Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren
31.2	Ameren	Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren
31.3	Ameren Missouri	Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Missouri
31.4	Ameren Missouri	Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Missouri
31.5	Ameren Illinois	Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Illinois
31.6	Ameren Illinois	Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Illinois
Section 1350 Certifications
32.1	Ameren	Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren
32.2	Ameren Missouri	Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Missouri
32.3	Ameren Illinois	Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Illinois
Interactive Data Files
101.INS	Ameren Companies	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	Ameren Companies	Inline XBRL Taxonomy Extension Schema Document
101.CAL	Ameren Companies	Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB	Ameren Companies	Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE	Ameren Companies	Inline XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF	Ameren Companies	Inline XBRL Taxonomy Extension Definition Document
104	Ameren Companies	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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

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

SIGNATURES

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

AMEREN CORPORATION

(Registrant)

/s/ Martin J. Lyons, Jr.

Martin J. Lyons, Jr.

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

UNION ELECTRIC COMPANY

(Registrant)

/s/ Martin J. Lyons, Jr.

Martin J. Lyons, Jr.

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

AMEREN ILLINOIS COMPANY

(Registrant)

/s/ Martin J. Lyons, Jr.

Martin J. Lyons, Jr.

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

Date: ~~May 10,~~November 8, 2019

5969



	Aggregate Fair Value of Derivative Liabilities^(a)		Cash Collateral Posted		Potential Aggregate Amount of Additional Collateral Required^(b)
Ameren Missouri	$	64	$	4	$	58
Ameren Illinois	39		—		29
Ameren	$	103	$	4	$	87



	March 31, 2019						March 31, 2018
	Ameren		Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri			Ameren Illinois
Accrued capital expenditures	$	208	$	92	$	106	$	202		$	73		$	114
Net realized and unrealized gain (loss) – nuclear decommissioning trust fund	64		64		—		(11		)	(11		)	—