Ipalco Enterprises 10-Q 2021 Q2 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2021

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

IPALCO ENTERPRISES, INC.

(Exact name of registrant as specified in its charter)

Indiana

(State or other jurisdiction of incorporation)

1-8644

(Commission File Number)

35-1575582

(IRS Employer Identification No.)

One Monument Circle

Indianapolis, Indiana 46204

(Address of principal executive offices, including zip code)

317-261-8261

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
N/A	N/A	N/A

Indicate by check mark whether the registrant (1) has 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) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

(The registrant was a voluntary filer during 2021 until its March 22, 2021 Registration Statement on Form S-4 filed with the Securities and Exchange Commission was declared effective on April 7, 2021. The registrant has filed all applicable reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months.)

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

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

Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

At August 4, 2021, 108,907,318 shares of IPALCO Enterprises, Inc. common stock were outstanding, of which 89,685,177 shares were owned by AES U.S. Investments, Inc. and 19,222,141 shares were owned by CDP Infrastructures Fund G.P., a wholly-owned subsidiary of La Caisse de dépôt et placement du Québec.

IPALCO ENTERPRISES, INC.

QUARTERLY REPORT ON FORM 10-Q 

For Quarter Ended June 30, 2021

TABLE OF CONTENTS

Item No.		Page No.
	DEFINED TERMS	4
	FORWARD-LOOKING STATEMENTS	5
	PART I - FINANCIAL INFORMATION
1.	Financial Statements
	Unaudited Condensed Consolidated Statements of Operations for the Three and Six Months Ended
	June 30, 2021 and 2020	7
	Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) for the Three and Six
	Months Ended June 30, 2021 and 2020	8
	Unaudited Condensed Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020	9
	Unaudited Condensed Consolidated Statements of Cash Flows for the Six Months Ended
	June 30, 2021 and 2020	10
	Unaudited Condensed Consolidated Statements of Common Shareholders' Equity and
	Noncontrolling Interest for the Three and Six Months Ended June 30, 2021 and 2020	11
	Notes to Unaudited Condensed Consolidated Financial Statements	12
	Note 1 - Overview and Summary of Significant Accounting Policies	12
	Note 2 - Regulatory Matters	14
	Note 3 - Fair Value	15
	Note 4 - Derivative Instruments and Hedging Activities	17
	Note 5 - Debt	19
	Note 6 - Income Taxes	21
	Note 7 - Benefit Plans	21
	Note 8 - Commitments and Contingencies	22
	Note 9 - Business Segment Information	22
	Note 10 - Revenue	23
	Note 11 - Leases	25
	Note 12 - Risks and Uncertainties	25
2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
3.	Quantitative and Qualitative Disclosure About Market Risk	41
4.	Controls and Procedures	41
	PART II - OTHER INFORMATION
1.	Legal Proceedings	41
1A.	Risk Factors	41
2.	Unregistered Sales of Equity Securities and Use of Proceeds	41
3.	Defaults Upon Senior Securities	41
4.	Mine Safety Disclosures	41
5.	Other Information	42
6.	Exhibits	42
	SIGNATURES	43

3

DEFINED TERMS
The following is a list of frequently used abbreviations or acronyms that are found in this Form 10-Q:
2020 Form 10-K	IPALCO’s Annual Report on Form 10-K for the year ended December 31, 2020, as amended
2024 IPALCO Notes	$405 million of 3.70% Senior Secured Notes due September 1, 2024
2030 IPALCO Notes	$475 million of 4.25% Senior Secured Notes due May 1, 2030
AES	The AES Corporation
AES Indiana	Indianapolis Power & Light Company, which does business as AES Indiana
AES U.S. Investments	AES U.S. Investments, Inc.
AOCL	Accumulated Other Comprehensive Loss
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
CAA	U.S. Clean Air Act
CCGT	Combined Cycle Gas Turbine
CCR	Coal Combustion Residuals
CDPQ	CDP Infrastructures Fund G.P., a wholly-owned subsidiary of La Caisse de dépôt et placement du Québec
CO2	Carbon Dioxide
COVID-19	The disease caused by the novel coronavirus that caused a global pandemic beginning in 2020.
CPCN	Certificate of Public Convenience and Necessity
CPP	Clean Power Plan
Credit Agreement	$250 million AES Indiana Revolving Credit Facilities Amended and Restated Credit Agreement, dated as of June 19, 2019
CSAPR	Cross-State Air Pollution Rule
CWA	U.S. Clean Water Act
DOJ	U.S. Department of Justice
DSM	Demand Side Management
EPA	U.S. Environmental Protection Agency
FAC	Fuel Adjustment Clause
FERC	Federal Energy Regulatory Commission
Financial Statements	Unaudited Condensed Consolidated Financial Statements of IPALCO in “Item 1. Financial Statements” included in Part I – Financial Information of this Form 10-Q
FTRs	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles in the United States
GHG	Greenhouse Gas
IDEM	Indiana Department of Environmental Management
IPALCO	IPALCO Enterprises, Inc.
IPL	Indianapolis Power & Light Company, which does business as AES Indiana
IRP	Integrated Resource Plan
IURC	Indiana Utility Regulatory Commission
kWh	Kilowatt hours
LIBOR	London Interbank Offered Rate
MISO	Midcontinent Independent System Operator, Inc.
MW	Megawatts
MWh	Megawatt hours
NAAQS	National Ambient Air Quality Standards
NOV	Notice of Violation
NOx	Nitrogen Oxide
NSR	New Source Review
Pension Plans	Employees’ Retirement Plan of Indianapolis Power & Light Company and Supplemental Retirement Plan of Indianapolis Power & Light Company
PSD	Prevention of Significant Deterioration
SEC	United States Securities and Exchange Commission

4

Service Company	AES US Services, LLC
SIP	State Implementation Plan
SO2	Sulfur Dioxide
Term Loan	$65 million IPALCO Term Loan Facility Credit Agreement, dated as of October 31, 2018
TDSIC	Transmission, Distribution, and Storage System Improvement Charge
U.S.	United States of America
USD	United States Dollars
VEBA	Voluntary Employees' Beneficiary Association

Throughout this document, the terms “the Company,” “we,” “us,” and “our” refer to IPALCO and its consolidated subsidiaries.

We encourage investors, the media, our customers and others interested in the Company to review the information we post at https://www.iplpower.com. None of the information on our website is incorporated into, or deemed to be a part of, this Quarterly Report on Form 10-Q or in any other report or document we file with the SEC, and any reference to our website is intended to be an inactive textual reference only.

FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q includes “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 including, in particular, the statements about our plans, strategies and prospects under the heading “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part I – Financial Information of this Form 10-Q. Forward-looking statements express an expectation or belief and contain a projection, plan or assumption with regard to, among other things, our future revenues, income, expenses or capital structure. Such statements of future events or performance are not guarantees of future performance and involve estimates, assumptions and uncertainties. The words “could,” “may,” “predict,” “anticipate,” “would,” “believe,” “estimate,” “expect,” “forecast,” “project,” “objective,” “intend,” “continue,” “should,” “plan,” and similar expressions, or the negatives thereof, are intended to identify forward-looking statements unless the context requires otherwise.

Some important factors that could cause our actual results or outcomes to differ materially from those discussed in the forward-looking statements include, but are not limited to:

•impacts of weather on retail sales;

•growth in our service territory and changes in retail demand and demographic patterns;

•weather-related damage to our electrical system;

•commodity and other input costs;

•performance of our suppliers;

•transmission and distribution system reliability and capacity, including natural gas pipeline system and supply constraints;

•regulatory actions and outcomes, including, but not limited to, the review and approval of our rates and charges by the IURC;

•federal and state legislation and regulations;

•changes in our credit ratings or the credit ratings of AES;  

•fluctuations in the value of pension plan assets, fluctuations in pension plan expenses and our ability to fund defined benefit pension plans;

•changes in financial or regulatory accounting policies;

•environmental matters, including costs of compliance with, and liabilities related to, current and future environmental laws and requirements;

•interest rates and the use of interest rate hedges, inflation rates and other costs of capital;

•the availability of capital;

•the ability of subsidiaries to pay dividends or distributions to IPALCO;

•level of creditworthiness of counterparties to contracts and transactions;

•labor strikes or other workforce factors, including the ability to attract and retain key personnel;

•facility or equipment maintenance, repairs and capital expenditures;

•significant delays or unanticipated cost increases associated with construction projects;

5

•the availability and cost of funds to finance working capital and capital needs, particularly during periods when the time lag between incurring costs and recovery is long and the costs are material;

•local economic conditions;

•cyber-attacks and information security breaches;

•catastrophic events such as fires, explosions, terrorist acts, acts of war, pandemic events, including the outbreak of the novel coronavirus COVID-19, or natural disasters such as floods, earthquakes, tornadoes, severe winds, ice or snow storms, droughts, or other similar occurrences;

•costs and effects of legal and administrative proceedings, audits, settlements, investigations and claims and the ultimate disposition of litigation;

•industry restructuring, deregulation and competition;

•issues related to our participation in MISO, including the cost associated with membership, our continued ability to recover costs incurred, and the risk of default of other MISO participants;

•changes in tax laws and the effects of our tax strategies;

•the use of derivative contracts;

•product development, technology changes, and changes in prices of products and technologies; and

•the risks and other factors discussed in this report and other IPALCO filings with the SEC.

All of the above factors are difficult to predict, contain uncertainties that may materially affect actual results, and many are beyond our control. See “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in IPALCO’s 2020 Form 10-K for a more detailed discussion of the foregoing and certain other factors that could cause actual results to differ materially from those reflected in any forward-looking statements. These risks may also be specifically described in our Quarterly Reports on Form 10-Q in "Part II - Item 1A. Risk Factors", Current Reports on Form 8-K and other documents that we may file from time to time with the SEC. Except as required by the federal securities laws, we undertake no obligation to publicly update or review any forward-looking information, whether as a result of new information, future events or otherwise. If one or more forward-looking statements are updated, no inference should be drawn that additional updates will be made with respect to those or other forward-looking statements. Our SEC filings are available to the public from the SEC’s website at www.sec.gov.

6

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS 

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Unaudited Condensed Consolidated Statements of Operations
(In Thousands)
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
REVENUES	$	330,587	$	311,503	$	692,788	$	668,885
OPERATING COSTS AND EXPENSES:
Fuel	52,840		43,351		137,571		112,139
Power purchased	41,748		43,082		66,331		78,549
Operation and maintenance	116,381		94,659		220,330		200,248
Depreciation and amortization	62,994		61,099		126,083		121,807
Taxes other than income taxes	8,745		11,606		21,696		23,664
Total operating costs and expenses	282,708		253,797		572,011		536,407
OPERATING INCOME	47,879		57,706		120,777		132,478
OTHER INCOME / (EXPENSE), NET:
Allowance for equity funds used during construction	1,331		1,160		2,705		2,017
Interest expense	(32,199)		(33,935)		(62,266)		(64,016)
Loss on early extinguishment of debt	0		(2,415)		0		(2,415)
Other income, net	4,704		1,772		9,318		1,979
Total other expense, net	(26,164)		(33,418)		(50,243)		(62,435)
EARNINGS FROM OPERATIONS BEFORE INCOME TAX	21,715		24,288		70,534		70,043
Less: Income tax expense	4,505		5,165		14,540		14,937
NET INCOME	17,210		19,123		55,994		55,106
Less: Dividends on preferred stock	804		804		1,607		1,607
NET INCOME APPLICABLE TO COMMON STOCK	$	16,406	$	18,319	$	54,387	$	53,499
See notes to unaudited condensed consolidated financial statements.

7

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Unaudited Condensed Consolidated Statements of Comprehensive Income/(Loss)
(In Thousands)
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
Net income applicable to common stock	$	16,406	$	18,319	$	54,387	$	53,499
Derivative activity:
Change in derivative fair value, net of income tax (expense)/benefit of $5,361, $1,388, $(4,294) and $13,910, for each respective period	(17,143)		(4,026)		12,907		(40,339)
Reclassification to earnings, net of income tax benefit of $431, $463, $284 and $463, for each respective period	1,376		1,344		920		1,344
Net change in fair value of derivatives	(15,767)		(2,682)		13,827		(38,995)
Other comprehensive income / (loss)	(15,767)		(2,682)		13,827		(38,995)
Net comprehensive income	$	639	$	15,637	$	68,214	$	14,504

See notes to unaudited condensed consolidated financial statements.

8

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Unaudited Condensed Consolidated Balance Sheets
(In Thousands)
	June 30,		December 31,
	2021		2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	20,629	$	20,502
Restricted cash	5		6,120
Accounts receivable, net of allowance for credit losses of $1,553 and $3,155, respectively	158,962		165,193
Inventories	81,460		95,506
Regulatory assets, current	62,188		45,430
Taxes receivable	20,709		24,384
Prepayments and other current assets	30,369		17,842
Total current assets	374,322		374,977
NON-CURRENT ASSETS:
Property, plant and equipment	6,479,619		6,530,395
Less: Accumulated depreciation	2,594,590		2,643,695
	3,885,029		3,886,700
Construction work in progress	246,871		209,584
Total net property, plant and equipment	4,131,900		4,096,284
OTHER NON-CURRENT ASSETS:
Intangible assets - net	56,765		59,141
Regulatory assets, non-current	372,339		392,801
Other non-current assets	58,879		46,716
Total other non-current assets	487,983		498,658
TOTAL ASSETS	$	4,994,205	$	4,969,919
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES:
Short-term debt and current portion of long-term debt (Note 5)	$	100,000	$	169,907
Accounts payable	151,511		127,089
Accrued taxes	26,404		26,620
Accrued interest	31,785		31,733
Customer deposits	27,747		27,929
Regulatory liabilities, current	12,503		30,036
Accrued and other current liabilities	15,606		19,453
Total current liabilities	365,556		432,767
NON-CURRENT LIABILITIES:
Long-term debt (Note 5)	2,652,396		2,556,278
Deferred income tax liabilities	291,517		275,714
Taxes payable	7,552		7,458
Regulatory liabilities, non-current	830,788		839,360
Accrued pension and other postretirement benefits	5,426		5,334
Asset retirement obligations	194,926		195,236
Derivative liabilities, non-current	46,015		63,215
Other non-current liabilities	13,565		13,785
Total non-current liabilities	4,042,185		3,956,380
Total liabilities	4,407,741		4,389,147
COMMITMENTS AND CONTINGENCIES (Note 8)
SHAREHOLDERS' EQUITY:
Paid in capital	580,831		588,966
Accumulated other comprehensive loss	(29,593)		(43,420)
Accumulated deficit	(24,558)		(24,558)
Total common shareholders' equity	526,680		520,988
Preferred stock of subsidiary	59,784		59,784
Total shareholders' equity	586,464		580,772
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$	4,994,205	$	4,969,919
See notes to unaudited condensed consolidated financial statements.

9

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Unaudited Condensed Consolidated Statements of Cash Flows
(In Thousands)
	Six Months Ended
	June 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	55,994	$	55,106
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	126,083		121,807
Amortization of deferred financing costs and debt discounts	1,977		2,087
Deferred income taxes and investment tax credit adjustments - net	5,866		860
Allowance for equity funds used during construction	(2,705)		(2,017)
Loss on early extinguishment of debt	0		2,415
Change in certain assets and liabilities:
Accounts receivable	6,231		(2,589)
Inventories	9,900		(23,346)
Accounts payable	22,316		(16,396)
Accrued and other current liabilities	(3,934)		(3,996)
Accrued taxes payable/receivable	3,553		21,144
Accrued interest	52		(1,951)
Pension and other postretirement benefit assets and liabilities	(8,284)		(3,452)
Short-term and long-term regulatory assets and liabilities	(21,026)		(799)
Prepayments and other current assets	(12,526)		(3,169)
Other - net	(4,398)		619
Net cash provided by operating activities	179,099		146,323
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(132,305)		(92,848)
Project development costs	(624)		(1,206)
Cost of removal and regulatory recoverable ARO payments	(12,562)		(19,488)
Other	0		101
Net cash used in investing activities	(145,491)		(113,441)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under revolving credit facilities	100,000		30,000
Repayments under revolving credit facilities	(75,000)		0
Long-term borrowings, net of discount	0		474,568
Retirement of long-term debt, including early payment premium	0		(472,135)
Distributions to shareholders	(62,579)		(53,227)
Preferred dividends of subsidiary	(1,607)		(1,607)
Deferred financing costs paid	(280)		(5,664)
Payments for financed capital expenditures	(36)		0
Other	(94)		(118)
Net cash used in financing activities	(39,596)		(28,183)
Net change in cash, cash equivalents and restricted cash	(5,988)		4,699
Cash, cash equivalents and restricted cash at beginning of period	26,622		48,552
Cash, cash equivalents and restricted cash at end of period	$	20,634	$	53,251
Supplemental disclosures of cash flow information:
Cash paid during the period for:
Interest (net of amount capitalized)	$	59,195	$	62,167
Income taxes	5,000		12,000
Non-cash investing activities:
Accruals for capital expenditures	$	56,465	$	35,617
See notes to unaudited condensed consolidated financial statements.

10

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Unaudited Condensed Consolidated Statements of Common Shareholders' Equity
and Noncontrolling Interest
For the Three and Six Months Ended June 30, 2021 and 2020
(In Thousands)
	Paid in Capital		Accumulated Other Comprehensive Loss		Accumulated Deficit		Total Common Shareholders' Equity		Cumulative Preferred Stock of Subsidiary
2021
Beginning Balance	$	588,966	$	(43,420)	$	(24,558)	$	520,988	$	59,784
Net comprehensive income/(loss)	—		29,594		37,981		67,575		803
Preferred stock dividends	—		—		—		—		(803)
Distributions to shareholders	—		—		(30,073)		(30,073)		—
Other	41		—		—		41		—
Balance at March 31, 2021	$	589,007	$	(13,826)	$	(16,650)	$	558,531	$	59,784
Net comprehensive income/(loss)	—		(15,767)		16,406		639		804
Preferred stock dividends	—		—		—		—		(804)
Distributions to shareholders(1)	(8,192)		—		(24,314)		(32,506)		—
Other	16		—		—		16		—
Balance at June 30, 2021	$	580,831	$	(29,593)	$	(24,558)	$	526,680	$	59,784
2020
Beginning Balance	$	590,784	$	(19,750)	$	(24,558)	$	546,476	$	59,784
Net comprehensive income/(loss)	—		(36,313)		35,180		(1,133)		803
Preferred stock dividends	—		—		—		—		(803)
Distributions to shareholders	—		—		(26,631)		(26,631)		—
Other	49		—		—		49		—
Balance at March 31, 2020	$	590,833	$	(56,063)	$	(16,009)	$	518,761	$	59,784
Net comprehensive income/(loss)	—		(2,682)		18,319		15,637		804
Preferred stock dividends	—		—		—		—		(804)
Distributions to shareholders	—		—		(26,596)		(26,596)		—
Other	37		—		—		37		—
Balance at June 30, 2020	$	590,870	$	(58,745)	$	(24,286)	$	507,839	$	59,784
(1) IPALCO made return of capital payments of $8.2 million during the three months ended June 30, 2021 for the portion of current year distributions to shareholders in excess of current year net income.

See notes to unaudited condensed consolidated financial statements.

11

IPALCO ENTERPRISES, INC. and SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements

1. OVERVIEW AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

IPALCO is a holding company incorporated under the laws of the state of Indiana. IPALCO is owned by AES U.S. Investments (82.35%) and CDPQ (17.65%). AES U.S. Investments is owned by AES U.S. Holdings, LLC (85%) and CDPQ (15%). IPALCO owns all of the outstanding common stock of IPL, which does business as AES Indiana. Substantially all of IPALCO’s business consists of generating, transmitting, distributing and selling of electric energy conducted through its principal subsidiary, AES Indiana. AES Indiana was incorporated under the laws of the state of Indiana in 1926. AES Indiana has approximately 514,000 retail customers in the city of Indianapolis and neighboring cities, towns and communities, and adjacent rural areas all within the state of Indiana, with the most distant point being approximately forty miles from Indianapolis. AES Indiana has an exclusive right to provide electric service to those customers. AES Indiana owns and operates 4 generating stations, all within the state of Indiana. AES Indiana’s largest generating station, Petersburg, is coal-fired, and AES Indiana retired 230 MW Petersburg Unit 1 on May 31, 2021 and has plans to retire 415 MW Petersburg Unit 2 in 2023 (for further discussion, see Note 2, "Regulatory Matters - IRP Filing and Replacement Generation"). The second largest station, Harding Street, uses natural gas and fuel oil to power combustion turbines. In addition, AES Indiana operates a 20 MW battery energy storage unit at this location, which provides frequency response. The third station, Eagle Valley, is a CCGT natural gas plant. The fourth station, Georgetown, is a small peaking station that uses natural gas to power combustion turbines. As of June 30, 2021, AES Indiana’s net electric generation capacity for winter is 3,475 MW and net summer capacity is 3,330 MW.

Consolidation

The accompanying Financial Statements include the accounts of IPALCO, AES Indiana and Mid-America Capital Resources, Inc., a non-regulated wholly-owned subsidiary of IPALCO. All significant intercompany amounts have been eliminated in consolidation.

Interim Financial Presentation

The accompanying Financial Statements are unaudited; however, they have been prepared in accordance with GAAP, as contained in the FASB ASC, for interim financial information and Article 10 of Regulation S-X issued by the SEC. Accordingly, they do not include all the information and footnotes required by GAAP for annual fiscal reporting periods. In the opinion of management, the interim financial information includes all adjustments of a normal recurring nature necessary for a fair presentation of the results of operations, financial position, comprehensive income, changes in equity, and cash flows. The electric utility business is affected by seasonal weather patterns throughout the year and, therefore, the operating revenues and associated operating expenses are not generated evenly by month during the year. These unaudited Financial Statements have been prepared in accordance with the accounting policies described in IPALCO’s 2020 Form 10-K and should be read in conjunction therewith.

Use of Management Estimates

The preparation of financial statements in conformity with GAAP requires that management make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements. The reported amounts of revenues and expenses during the reporting period may also be affected by the estimates and assumptions that management is required to make. Actual results may differ from those estimates.

12

Cash, Cash Equivalents and Restricted Cash

The following table provides a summary of cash, cash equivalents and restricted cash amounts as shown on the Unaudited Condensed Consolidated Statements of Cash Flows:

	June 30,		December 31,
	2021		2020
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	20,629	$	20,502
Restricted cash	5		6,120
Total cash, cash equivalents and restricted cash	$	20,634	$	26,622

Accounts Receivable

The following table summarizes our accounts receivable balances at June 30, 2021 and December 31, 2020:

	June 30,		December 31,
	2021		2020
	(In Thousands)
Accounts receivable, net
Customer receivables	$	84,477	$	91,335
Unbilled revenue	66,530		72,334
Amounts due from related parties	0		490
Other	9,508		4,189
Allowance for credit losses	(1,553)		(3,155)
Total accounts receivable, net	$	158,962	$	165,193

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the periods indicated (in Thousands):

Six Months Ended June 30, 2021	Beginning Allowance Balance at January 1, 2021		Current Period Provision		Write-offs Charged Against Allowances		Recoveries Collected		Ending Allowance Balance at June 30, 2021
Allowance for credit losses	$	3,155	$	1,030	$	(3,741)	$	1,109	$	1,553

Six Months Ended June 30, 2020	Beginning Allowance Balance at January 1, 2020		Current Period Provision		Write-offs Charged Against Allowances		Recoveries Collected		Ending Allowance Balance at June 30, 2020
Allowance for credit losses	$	921	$	4,312	$	(3,697)	$	2,517	$	4,053

The allowance for credit losses primarily relates to utility customer receivables, including unbilled amounts. Expected credit loss estimates are developed by disaggregating customers into those with similar credit risk characteristics and using historical credit loss experience. In addition, we also consider how current and future economic conditions are expected to impact collectability, as applicable, including the economic impacts of the COVID-19 pandemic on our receivable balance as of June 30, 2021. Amounts are written off when reasonable collections efforts have been exhausted. During 2021, the current period provision and allowance for credit losses have decreased due to lower past due customer receivable balances.

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Inventories

The following table summarizes our inventories balances at June 30, 2021 and December 31, 2020:

	June 30,		December 31,
	2021		2020
	(In Thousands)
Inventories
Fuel	$	21,328	$	36,953
Materials and supplies, net	60,132		58,553
Total inventories	$	81,460	$	95,506

AOCL

The amounts reclassified out of AOCL by component during the three and six months ended June 30, 2021 and 2020 are as follows (in thousands):

Details about AOCL components	Affected line item in the Condensed Consolidated Statements of Operations	Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020
Gains and losses on cash flow hedges (Note 4):	Interest expense	$	1,807	$	1,807	$	1,204	$	1,807
	Income tax expense	(431)		(463)		(284)		(463)
Total reclassifications for the period, net of income taxes		$	1,376	$	1,344	$	920	$	1,344

See Note 4, "Derivative Instruments and Hedging Activities - Cash Flow Hedges" for further information on the changes in the components of AOCL.

New Accounting Pronouncements Issued But Not Yet Effective

The following table provides a brief description of recent accounting pronouncements that could have a material impact on the Company’s Financial Statements once adopted. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on the Company’s Financial Statements.

New Accounting Standards Issued But Not Yet Effective
ASU Number and Name	Description	Date of Adoption	Effect on the Financial Statements upon adoption
2020-04, Reference Rate Form (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting	The amendments in these updates provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference to LIBOR or another reference rate expected to be discontinued by reference rate reform, and clarify that certain optional expedients and exceptions in Topic 848 for contract modifications and hedge accounting apply to derivatives that are affected by the discounting transition. These amendments are effective for a limited period of time (March 12, 2020 - December 21, 2022).	March 12, 2020 - December 31, 2022	The Company is currently evaluating the impact of adopting the standard on the Financial Statements.

2. REGULATORY MATTERS

IRP Filing and Replacement Generation

On February 5, 2021, AES Indiana announced an agreement to acquire a 195 MW solar project to be developed in Clinton County, Indiana and expected to be completed in 2023. On February 12, 2021, AES Indiana filed a petition and case-in-chief with the IURC seeking a CPCN for this solar project and on June 16, 2021, AES Indiana received an order from the IURC approving the project.

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On August 2, 2021, AES Indiana announced plans to acquire a 250 MW solar and 180 MWh energy storage facility to be developed in Pike County, Indiana and expected to be completed in 2024. The plans require approval from the IURC. On July 30, 2021, AES Indiana filed a petition and case-in-chief with the IURC seeking a CPCN for this solar project.

On February 26, 2021, as a result of the plans to retire approximately 630 MW of coal-fired generation at Petersburg Units 1 and 2 in 2021 and 2023, respectively, AES Indiana filed a petition with the IURC for approvals and cost recovery associated with these retirements, including: (1) approval of AES Indiana's creation of regulatory assets for the net book value of Petersburg units 1 and 2 upon retirement; (2) amortization of the regulatory assets based upon the Company’s depreciation rates; and (3) recovery of the regulatory assets through inclusion in AES Indiana’s rate base and ongoing amortization in AES Indiana’s future rate cases. AES Indiana retired 230 MW Petersburg Unit 1 on May 31, 2021 and has $65.6 million of Petersburg Unit 1 retirement costs recorded in long-term regulatory assets as of June 30, 2021.

Excess Distributed Generation Rates

On March 1, 2021, AES Indiana filed a petition with the IURC for approval of its proposed rate for the procurement of excess distributed generation ("EDG") and related consumer EDG credit issues. The EDG rate will replace the current net metering program and will be offered beginning July 2022, when net metering is no longer available to new customers.

Electric Vehicle Portfolio Program

On March 2, 2021, AES Indiana filed with the IURC a request to approve its Electric Vehicle (EV) portfolio and associated accounting and ratemaking treatment. The EV portfolio aims to accelerate electric car adoption by reducing friction in the car buying process, and by providing customers incentives to optimize electric car charging during off-peak periods. The EV portfolio is designed to produce net benefits for all customers through new retail margins and grid optimization. The projected costs to successfully implement the services proposed in the EV portfolio are estimated at $5.1 million over the 3 year period. AES Indiana requested approval to defer as a regulatory asset and recover in future base rates the cost necessary to implement the EV portfolio, including carrying charges.

3. FAIR VALUE

The fair value of financial assets and liabilities approximate their reported carrying amounts. The estimated fair values of the Company’s assets and liabilities have been determined using available market information. As these amounts are estimates and based on hypothetical transactions to sell assets or transfer liabilities, the use of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts. For further information on our valuation techniques and policies, see Note 4, "Fair Value" to IPALCO’s 2020 Form 10-K.

Financial Assets

VEBA Assets

IPALCO has VEBA investments that are to be used to fund certain employee postretirement health care benefit plans. These assets are primarily comprised of open-ended mutual funds, which are valued using the net assets value per unit. These investments are recorded at fair value within "Other non-current assets" on the accompanying Unaudited Condensed Consolidated Balance Sheets and classified as equity securities. All changes to fair value on the VEBA investments are included in income in the period that the changes occur. These changes to fair value were not material for the periods covered by this report. Any unrealized gains or losses are recorded in "Other income / (expense), net" on the accompanying Unaudited Condensed Consolidated Statements of Operations.

FTRs

In connection with AES Indiana’s participation in MISO, in the second quarter of each year AES Indiana is granted financial instruments that can be converted into cash or FTRs based on AES Indiana’s forecasted peak load for the period. FTRs are used in the MISO market to hedge AES Indiana’s exposure to congestion charges, which result from constraints on the transmission system. AES Indiana’s FTRs are valued at the cleared auction prices for FTRs in MISO’s annual auction. Because of the infrequent nature of this valuation, the fair value assigned to the FTRs is

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considered a Level 3 input under the fair value hierarchy required by ASC 820. An offsetting regulatory liability has been recorded as these revenues or costs will be flowed through to customers through the FAC. As such, there is no impact on our Unaudited Condensed Consolidated Statements of Operations.

Forward Power Contracts

In the second quarter of 2021, we entered into forward purchase power contracts. The forward power contracts have a combined notional amount outstanding of 398,960 MWhs. All changes in the market value of the forward power contracts are recorded in the Consolidated Statements of Operations in the period in which the change occurred. See also Note 4, "Derivative Instruments and Hedging Activities - Derivatives Not Designated as Hedge" for further information.

Financial Liabilities

Interest Rate Hedges

In March 2019, we entered into forward interest rate hedges, which were amended in April 2020. The interest rate hedges have a combined notional amount of $400.0 million. All changes in the market value of the interest rate hedges are recorded in AOCL. See also Note 4, "Derivative Instruments and Hedging Activities - Cash Flow Hedges" for further information.

Recurring Fair Value Measurements

The fair value of assets and liabilities at June 30, 2021 and December 31, 2020 measured on a recurring basis and the respective category within the fair value hierarchy for IPALCO was determined as follows:

Assets and Liabilities at Fair Value
			Level 1		Level 2		Level 3
	Fair value at June 30, 2021		Based on quoted market prices in active markets		Other observable inputs		Unobservable inputs
	(In Thousands)
Financial assets:
VEBA investments:
Money market funds	$	16	$	16	$	0	$	0
Mutual funds	3,515		0		3,515		0
Total VEBA investments	3,531		16		3,515		0
Financial transmission rights	2,658		0		0		2,658
Forward power contracts	2,651		0		2,651		0
Total financial assets measured at fair value	$	8,840	$	16	$	6,166	$	2,658
Financial liabilities:
Interest rate hedges	$	46,015	$	0	$	46,015	$	0
Total financial liabilities measured at fair value	$	46,015	$	0	$	46,015	$	0

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Assets and Liabilities at Fair Value
			Level 1		Level 2		Level 3
	Fair value at December 31, 2020		Based on quoted market prices in active markets		Other observable inputs		Unobservable inputs
	(In Thousands)
Financial assets:
VEBA investments:
Money market funds	$	16	$	16	$	0	$	0
Mutual funds	3,209		0		3,209		0
Total VEBA investments	3,225		16		3,209		0
Financial transmission rights	543		0		0		543
Total financial assets measured at fair value	$	3,768	$	16	$	3,209	$	543
Financial liabilities:
Interest rate hedges	$	63,215	$	0	$	63,215	$	0
Total financial liabilities measured at fair value	$	63,215	$	0	$	63,215	$	0

Financial Instruments not Measured at Fair Value in the Consolidated Balance Sheets

Debt

The fair value of our outstanding fixed-rate debt has been determined on the basis of the quoted market prices of the specific securities issued and outstanding. In certain circumstances, the market for such securities was inactive and therefore the valuation was adjusted to consider changes in market spreads for similar securities. Accordingly, the purpose of this disclosure is not to approximate the value on the basis of how the debt might be refinanced.

The following table shows the face value and the fair value of fixed-rate and variable-rate indebtedness (Level 2) for the periods ending:  

	June 30, 2021				December 31, 2020
	Face Value		Fair Value		Face Value		Fair Value
	(In Thousands)
Fixed-rate	$	2,683,800	$	3,179,608	$	2,683,800	$	3,295,588
Variable-rate	100,000		100,000		75,000		75,000
Total indebtedness	$	2,783,800	$	3,279,608	$	2,758,800	$	3,370,588

The difference between the face value and the carrying value of this indebtedness consists of the following:

•unamortized deferred financing costs of $24.9 million and $26.0 million at June 30, 2021 and December 31, 2020, respectively; and

•unamortized discounts of $6.5 million and $6.6 million at June 30, 2021 and December 31, 2020, respectively.

4. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

We use derivatives principally to manage the interest rate risk associated with refinancing our long-term debt and the risk of price changes for purchased power. The derivatives that we use to economically hedge these risks are governed by our risk management policies for forward and futures contracts. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. We monitor and value derivative positions monthly as part of our risk management processes. We use published sources for pricing, when possible, to mark positions to market. All of our derivative instruments are used for risk management purposes and are designated as cash flow hedges if they qualify under ASC 815 for accounting purposes.

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For further information on the Company’s derivative and hedge accounting policies, see Note 1, "Overview and Summary of Significant Accounting Policies - Financial Derivatives" and Note 5, "Derivative Instruments and Hedging Activities" to IPALCO’s 2020 Form 10-K.

At June 30, 2021, AES Indiana's outstanding derivative instruments were as follows:

Commodity	Accounting Treatment (a)	Unit	Purchases (in thousands)		Sales (in thousands)		Net Purchases/(Sales) (in thousands)
Interest rate hedges	Designated	USD	$	400,000	$	0	$	400,000
FTRs	Not Designated	MWh	13,182		0		13,182
Forward power contracts	Not Designated	MWh	399		0		399

(a)    Refers to whether the derivative instruments have been designated as a cash flow hedge.

Cash Flow Hedges

As part of our risk management processes, we identify the relationships between hedging instruments and hedged items, as well as the risk management objective and strategy for undertaking various hedge transactions. The fair values of cash flow hedges determined by current public market prices will continue to fluctuate with changes in market prices up to contract expiration.

The following tables provide information on gains or losses recognized in AOCL for the cash flow hedges for the periods indicated:

	Interest Rate Hedges for the Three Months Ended June 30,
$ in thousands (net of tax)	2021		2020
Beginning accumulated derivative loss in AOCL	$	(13,826)	$	(56,063)
Net gains / (losses) associated with current period hedging transactions	(17,143)		(4,026)
Net (gains) / losses reclassified to interest expense, net of tax	1,376		1,344
Ending accumulated derivative loss in AOCL	$	(29,593)	$	(58,745)

	Interest Rate Hedges for the Six Months Ended June 30,
$ in thousands (net of tax)	2021		2020
Beginning accumulated derivative loss in AOCL	$	(43,420)	$	(19,750)
Net gains / (losses) associated with current period hedging transactions	12,907		(40,339)
Net (gains) / losses reclassified to interest expense, net of tax	920		1,344
Ending accumulated derivative loss in AOCL	$	(29,593)	$	(58,745)
Loss expected to be reclassified to earnings in the next twelve months	$	(5,375)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	39

Derivatives Not Designated as Hedge

FTRs and the forward power contracts do not qualify for hedge accounting or the normal purchases and sales exceptions under ASC 815. Accordingly, FTRs are recorded at fair value when acquired and subsequently amortized over the annual period as they are used. FTRs are initially recorded at fair value using the income approach. The forward power contracts are recorded at fair value with changes in the fair value charged or credited to the Consolidated Statements of Operations in the period in which the change occurred. Forward power contracts are fair valued using the market approach. This is commonly referred to as "MTM accounting". Realized gains and losses on the forward power contracts will be included in future FAC filings, therefore any realized and unrealized gains and losses are deferred as regulatory liabilities or regulatory assets. For the three and six months ended June 30, 2021, there were unrealized gains of $2.7 million and realized gains of $0.8 million related to the forward power contracts that were deferred and included with deferred fuel costs in "Regulatory assets, current" on the accompanying Condensed Consolidated Balance Sheets.

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Certain qualifying derivative instruments have been designated as normal purchases or normal sales contracts, as provided under GAAP. Derivative contracts that have been designated as normal purchases or normal sales under GAAP are not subject to hedge or mark to market accounting and are recognized in the consolidated statements of operations on an accrual basis.

When applicable, IPALCO has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. As of June 30, 2021, IPALCO did not have any offsetting positions.

The following table summarizes the fair value, balance sheet classification and hedging designation of IPALCO's derivative instruments (in thousands):

Commodity	Hedging Designation	Balance sheet classification	June 30, 2021		December 31, 2020
Financial transmission rights	Not a Cash Flow Hedge	Prepayments and other current assets	$	2,658	$	543
Forward power contracts	Not a Cash Flow Hedge	Prepayments and other current assets	$	2,651	$	0
Interest rate hedges	Cash Flow Hedge	Derivative liabilities, non-current	$	46,015	$	63,215

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5. DEBT

Long-Term Debt

The following table presents our long-term debt:

		June 30,		December 31,
Series	Due	2021		2020
		(In Thousands)
AES Indiana first mortgage bonds:
3.875% (1)	August 2021	$	55,000	$	55,000
3.875% (1)	August 2021	40,000		40,000
3.125% (1)	December 2024	40,000		40,000
6.60%	January 2034	100,000		100,000
6.05%	October 2036	158,800		158,800
6.60%	June 2037	165,000		165,000
4.875%	November 2041	140,000		140,000
4.65%	June 2043	170,000		170,000
4.50%	June 2044	130,000		130,000
4.70%	September 2045	260,000		260,000
4.05%	May 2046	350,000		350,000
4.875%	November 2048	105,000		105,000
0.75% (2)	April 2026	30,000		30,000
0.95% (2)	April 2026	60,000		60,000
Unamortized discount – net		(5,930)		(6,006)
Deferred financing costs		(16,939)		(17,384)
Total AES Indiana first mortgage bonds		1,780,931		1,780,410
Total Long-term Debt – AES Indiana		1,780,931		1,780,410
Long-term Debt – IPALCO:
3.70% Senior Secured Notes	September 2024	405,000		405,000
4.25% Senior Secured Notes	May 2030	475,000		475,000
Unamortized discount – net		(576)		(625)
Deferred financing costs		(7,959)		(8,600)
Total Long-term Debt – IPALCO		871,465		870,775
Total Consolidated IPALCO Long-term Debt		2,652,396		2,651,185
Less: Current Portion of Long-term Debt		0		94,907
Net Consolidated IPALCO Long-term Debt		$	2,652,396	$	2,556,278

(1)First mortgage bonds issued to the Indiana Finance Authority, to secure the loan of proceeds from tax-exempt bonds issued by the Indiana Finance Authority.

(2)First mortgage bonds issued to the Indiana Finance Authority, to secure the loan of proceeds from tax-exempt bonds issued by the Indiana Finance Authority. The notes have a final maturity date of December 31, 2038, but are subject to a mandatory put in April 2026.

AES Indiana First Mortgage Bonds

In July 2021, the Indiana Finance Authority issued on behalf of AES Indiana an aggregate principal amount of $95 million of Environmental Facilities Refunding Revenue Bonds, Series 2021A&B. AES Indiana issued $95 million aggregate principal amount of first mortgage bonds to the Indiana Finance Authority in two series: $55 million Series 2021A bonds at 1.40% due August 1, 2029 and $40 million Series 2021B notes at 0.65% due August 1, 2025 to secure the loan of proceeds from these bonds issued by the Indiana Finance Authority. Proceeds of the bonds were used to refund $95 million of Indiana Finance Authority Environmental Facilities Refunding Revenue Bonds Series 2011A&B due August 1, 2021 at a redemption price of 100%. As a result of this refinancing, the $95 million of Indiana Finance Authority Environmental Facilities Refunding Revenue Bonds Series 2011A&B due August 1, 2021 are presented as long-term debt as of June 30, 2021.

IPALCO’s Senior Secured Notes and Term Loan

In April 2020, IPALCO completed the sale of the $475 million aggregate principal amount of 4.25% 2030 IPALCO Notes pursuant to Rule 144A and Regulation S under the Securities Act of 1933, as amended. We used the net

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proceeds from this offering to retire the $65 million Term Loan on April 14, 2020. The remaining net proceeds, together with cash on hand, were used to redeem the 2020 IPALCO Notes on May 14, 2020, and to pay certain related fees, expenses and make-whole premiums. A loss on early extinguishment of debt of $2.4 million for the 2020 IPALCO Notes is included as a separate line item within "Other Income/(Expense), Net" in the accompanying Unaudited Condensed Consolidated Statements of Operations.

Pursuant to a registration rights agreement dated April 14, 2020, IPALCO agreed to register the 2030 IPALCO Notes under the Securities Act by filing an exchange offer registration statement or, under specified circumstances, a shelf registration statement with the SEC. IPALCO filed a registration statement on Form S-4 with respect to the 2030 IPALCO Notes with the SEC on March 22, 2021 in respect of its obligations under such registration rights agreement, and this registration statement was declared effective on April 7, 2021. The exchange offer closed on May 11, 2021.

Line of Credit

As of June 30, 2021 and December 31, 2020, AES Indiana had $100.0 million and $75.0 million in outstanding borrowings on the committed line of credit, respectively. 

6. INCOME TAXES

Effective Tax Rate

IPALCO’s effective combined state and federal income tax rate was 20.7% and 20.6% for the three and six months ended June 30, 2021, respectively, as compared to 21.3% and 21.3% for the three and six months ended June 30, 2020, respectively. The decrease in the effective tax rate versus the comparable periods was primarily due to the impact of the reversal of excess deferred income taxes as a percentage of pre-tax income. The rates for the three and six months ended June 30, 2021 are lower than the combined federal and state statutory rate of 25.01% primarily due to the flowthrough of the net tax benefit related to the reversal of excess deferred taxes of AES Indiana, which was partially offset by the net tax expense related to the amortization of allowance for equity funds used during construction.

7. BENEFIT PLANS

Pension Expense

The following table presents net periodic benefit (credit) / cost information relating to the Pension Plans combined:

	For the Three Months Ended				For the Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
	(In Thousands)				(In Thousands)
Components of net periodic benefit (credit) / cost:
Service cost	$	2,335	$	2,068	$	4,669	$	4,136
Interest cost	3,915		5,538		7,830		11,076
Expected return on plan assets	(10,454)		(9,445)		(20,908)		(18,890)
Amortization of prior service cost	736		919		1,472		1,838
Amortization of actuarial loss	1,382		2,028		2,764		4,057
Net periodic benefit (credit) / cost	$	(2,086)	$	1,108	$	(4,173)	$	2,217

The components of net periodic benefit (credits) / costs other than service costs are included in "Other income, net" in the Unaudited Condensed Consolidated Statements of Operations.

In addition, AES Indiana provides postretirement health care benefits to certain active or retired employees and the spouses of certain active or retired employees. These postretirement health care benefits and the related unfunded obligation of $4.4 million and $4.3 million at June 30, 2021 and December 31, 2020, respectively, were not material to the Financial Statements in the periods covered by this report.

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8. COMMITMENTS AND CONTINGENCIES

Legal Loss Contingencies

IPALCO and AES Indiana are involved in litigation arising in the normal course of business. We accrue for litigation and claims when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. As of June 30, 2021 and December 31, 2020, total legal loss contingencies accrued were $13.4 million and $13.4 million, respectively, which were included in "Other Non-Current Liabilities," on the accompanying Unaudited Condensed Consolidated Balance Sheets. A significant portion of these accrued liabilities relate to a personal injury judgement that is currently under appeal and involved injuries to a contractor. We maintain an amount of insurance protection for such litigation that we believe is adequate. While the ultimate outcome of outstanding litigation cannot be predicted with certainty, management believes that final outcomes will not have a material adverse effect on IPALCO’s results of operations, financial condition and cash flows.

Environmental Loss Contingencies

We are subject to various federal, state, regional and local environmental protection and health and safety laws and regulations governing, among other things, the generation, storage, handling, use, disposal and transportation of regulated materials, including ash; the use and discharge of water used in generation boilers and for cooling purposes; the emission and discharge of hazardous and other materials into the environment; and the health and safety of our employees. These laws and regulations often require a lengthy and complex process of obtaining and renewing permits and other governmental authorizations from federal, state and local agencies. Violation of these laws, regulations or permits can result in substantial fines, other sanctions, permit revocation and/or facility shutdowns. We cannot assure that we have been or will be at all times in full compliance with such laws, regulations and permits.

New Source Review and Other CAA NOVs

In October 2009, AES Indiana received a NOV and Finding of Violation from the EPA pursuant to the CAA Section 113(a). The NOV alleged violations of the CAA at AES Indiana’s 3 primarily coal-fired electric generating facilities at the time, dating back to 1986. The alleged violations primarily pertain to the PSD and non-attainment New Source Review (NSR) requirements under the CAA. In addition, on October 1, 2015, AES Indiana received a NOV from the EPA pursuant to CAA Section 113(a) alleging violations of the CAA, the Indiana SIP, and the Title V operating permit related to alleged particulate matter and opacity violations at AES Indiana Petersburg Unit 3. Also, on February 5, 2016, the EPA issued a NOV pursuant to CAA Section 113(a) alleging violations of PSD, non-attainment NSR and other CAA regulations, the Indiana SIP, and the Title V operating permit at Petersburg Generating Station. On August 31, 2020, AES Indiana reached a settlement with the EPA, the DOJ and IDEM resolving the purported violations of the CAA with respect to the four coal-fired generation units at AES Indiana's Petersburg location. The settlement agreement, in the form of a proposed judicial consent decree, was approved and entered by the U.S. District Court for the Southern District of Indiana on March 23, 2021, and includes, among other items, the following requirements: annual caps on NOx and SO2 emissions and more stringent emissions limits than AES Indiana's current Title V air permit; payment of civil penalties totaling $1.525 million (the payment of which was satisfied by AES Indiana in April 2021); a $5 million environmental mitigation project consisting of the construction and operation of a new, non-emitting source of generation at the site; expenditure of $0.325 million on a state-only environmentally beneficial project to preserve local, ecologically-significant lands; and retirement of Units 1 and 2 prior to July 1, 2023. If AES Indiana does not meet this retirement obligation, it must install a Selective Non-Catalytic Reduction System (SNCR) on Unit 4. AES Indiana had a contingent liability recorded related to these New Source Review and other CAA NOV matters.

9. BUSINESS SEGMENT INFORMATION

Operating segments are components of an enterprise that engage in business activities from which it may earn revenues and incur expenses, for which separate financial information is available, and is evaluated regularly by the chief operating decision maker in assessing performance and deciding how to allocate resources. Substantially all of our business consists of the generation, transmission, distribution and sale of electric energy conducted through AES Indiana, which is a vertically integrated electric utility. IPALCO’s reportable business segment is its utility segment, with all other nonutility business activities aggregated separately. The “All Other” nonutility category primarily includes the 2024 IPALCO Notes and 2030 IPALCO Notes and related interest expense, balance

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associated with IPALCO's interest rate hedges, cash and other immaterial balances. The accounting policies of the identified segment are consistent with those policies and procedures described in the summary of significant accounting policies.

The following table provides information about IPALCO’s business segments (in thousands):

	Three Months Ended						Three Months Ended
	June 30, 2021						June 30, 2020
	Utility		All Other		Total		Utility		All Other		Total
Revenues	$	330,587	$	0	$	330,587	$	311,503	$	0	$	311,503
Depreciation and amortization	$	62,994	$	0	$	62,994	$	61,099	$	0	$	61,099
Interest expense	$	21,255	$	10,944	$	32,199	$	21,882	$	12,053	$	33,935
Earnings/(loss) from operations before income tax	$	32,587	$	(10,872)	$	21,715	$	38,770	$	(14,482)	$	24,288
	Six Months Ended						Six Months Ended
	June 30, 2021						June 30, 2020
	Utility		All Other		Total		Utility		All Other		Total
Revenues	$	692,788	$	0	$	692,788	$	668,885	$	0	$	668,885
Depreciation and amortization	$	126,083	$	0	$	126,083	$	121,807	$	0	$	121,807
Interest expense	$	42,776	$	19,490	$	62,266	$	43,802	$	20,214	$	64,016
Earnings/(loss) from operations before income tax	$	89,882	$	(19,348)	$	70,534	$	93,737	$	(23,694)	$	70,043
Capital expenditures(1)	$	132,341	$	0	$	132,341	$	92,848	$	0	$	92,848
	As of June 30, 2021						As of December 31, 2020
	Utility		All Other		Total		Utility		All Other		Total
Total assets	$	4,975,344	$	18,861	$	4,994,205	$	4,952,408	$	17,511	$	4,969,919

(1) Capital expenditures includes payments for financed capital expenditures of $36.0 thousand and $0.0 thousand for the six months ended June 30, 2021 and June 30, 2020, respectively.

10. REVENUE

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities. Please see Note 13, “Revenue” to IPALCO’s 2020 Form 10-K for further discussion of our retail, wholesale and miscellaneous revenues.

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AES Indiana’s revenue from contracts with customers was $318.5 million and $302.4 million for the three months ended June 30, 2021 and 2020, respectively, and $672.2 million and $654.3 million for the six months ended June 30, 2021 and 2020, respectively. The following table presents our revenue from contracts with customers and other revenue (in thousands):

	For the Three Months Ended		For the Three Months Ended
	June 30, 2021		June 30, 2020
Retail Revenues
Retail revenue from contracts with customers:
Residential	$	129,254	$	127,752
Small commercial and industrial	48,208		43,402
Large commercial and industrial	127,009		119,302
Public lighting	2,270		2,309
Other (1)	4,175		2,805
Total retail revenue from contracts with customers	310,916		295,570
Alternative revenue programs	11,710		8,789
Wholesale Revenues
Wholesale revenues from contracts with customers:	4,918		4,501
Miscellaneous Revenues
Transmission and other revenue from contracts with customers	2,692		2,329
Other miscellaneous revenues (2)	351		314
Total Revenues	$	330,587	$	311,503

(1)Other retail revenue from contracts with customers includes miscellaneous charges to customers

(2)Other miscellaneous revenue includes lease and other miscellaneous revenues not accounted for under ASC 606

	For the Six Months Ended		For the Six Months Ended
	June 30, 2021		June 30, 2020
Retail Revenues
Retail revenue from contracts with customers:
Residential	$	289,757	$	283,161
Small commercial and industrial	102,725		97,655
Large commercial and industrial	240,449		241,340
Public lighting	4,456		4,614
Other (1)	8,366		6,693
Total retail revenue from contracts with customers	645,753		633,463
Alternative revenue programs	19,305		13,684
Wholesale Revenues
Wholesale revenues from contracts with customers:	21,027		15,809
Miscellaneous Revenues
Transmission and other revenue from contracts with customers	5,373		5,061
Other miscellaneous revenues (2)	1,330		868
Total Revenues	$	692,788	$	668,885

(1)Other retail revenue from contracts with customers includes miscellaneous charges to customers

(2)Other miscellaneous revenue includes lease and other miscellaneous revenues not accounted for under ASC 606

The balances of receivables from contracts with customers were $149.8 million and $163.8 million as of June 30, 2021 and December 31, 2020, respectively. Payment terms for all receivables from contracts with customers typically do not extend beyond 30 days.

Contract Balances — The timing of revenue recognition, billings, and cash collections results in accounts receivable and contract liabilities. The contract liabilities from contracts with customers were $0.0 million and $0.5 million as of June 30, 2021 and December 31, 2020, respectively. During the three months ended June 30, 2021 and 2020, we recognized revenue of $0.2 million and $0.3 million related to this contract liability balance, respectively. During the

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six months ended June 30, 2021 and 2020, we recognized revenue of $0.5 million and $0.7 million related to this contract liability balance, respectively.

11. LEASES

LESSOR

The Company is the lessor under operating leases for land, office space and operating equipment. Minimum lease payments from such contracts are recognized as operating lease revenue on a straight-line basis over the lease term whereas contingent rentals are recognized when earned. Lease revenue included in the Unaudited Condensed Consolidated Statements of Operations was $0.3 million and $0.2 million for the three months ended June 30, 2021 and 2020, respectively, and was $0.6 million and $0.5 million for the six months ended June 30, 2021 and 2020, respectively. Underlying gross assets and accumulated depreciation of operating leases included in Total net property, plant and equipment on the Unaudited Condensed Consolidated Balance Sheet were $4.6 million and $1.0 million, respectively, as of June 30, 2021 and $4.3 million and $0.8 million, respectively, as of December 31, 2020.

The option to extend or terminate a lease is based on customary early termination provisions in the contract. The Company has not recognized any early terminations as of June 30, 2021.

The following table shows the future minimum lease receipts as of June 30, 2021 for the remainder of 2021 through 2025 and thereafter (in thousands):

	Operating Leases
2021	$	443
2022	903
2023	906
2024	786
2025	553
Thereafter	2,113
Total	$	5,704

12. RISKS AND UNCERTAINTIES

COVID-19 Pandemic

The COVID-19 pandemic has impacted global economic activity, including electricity and energy consumption, and caused significant volatility in financial markets. Many countries, including the U.S., reacted to the pandemic by instituting quarantines and mandating business and school closures or limitations and other social distancing measures. Responses to the COVID-19 pandemic by the State of Indiana and its residents and businesses continue to evolve as vaccine availability and usage continues and the State and businesses review and adjust the scope requirements of social distancing measures. Social distancing measures designed to slow the spread of the virus, such as business closures and operations limitations, impact energy demand within our service territory. We continue to take a variety of measures in response to the spread of COVID-19 to ensure our ability to generate, transmit, distribute and sell electric energy, ensure the health and safety of our employees, contractors, customers and communities and provide essential services to the communities in which we operate. In addition to the impacts to demand within our service territory, we also have incurred and may continue to incur expenses relating to COVID-19, including those that relate to events outside of our control. The magnitude and duration of the COVID-19 pandemic is unknown at this time and may have material and adverse effects on our results of operations, financial condition and cash flows in future periods.

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

The following discussion and analysis should be read in conjunction with the Financial Statements and the notes thereto included in “Item 1. Financial Statements” included in Part I – Financial Information of this Form 10-Q.

FORWARD-LOOKING INFORMATION

The following discussion may contain forward-looking statements regarding us, our business, prospects and our results of operations, including our expectations regarding the impact of the COVID-19 pandemic on our business, that are subject to certain risks and uncertainties posed by many factors and events that could cause our actual business, prospects and results of operations to differ materially from those that may be anticipated by such forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those described in “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in IPALCO’s 2020 Form 10-K and subsequent filings with the SEC. Readers are cautioned not to place undue reliance on these forward-looking statements which speak only as of the date of this report. We undertake no obligation to revise any forward-looking statements in order to reflect events or circumstances that may subsequently arise. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect to those or other forward-looking statements. Readers are urged to carefully review and consider the various disclosures made by us in this report and in our other reports filed with the SEC that advise of the risks and uncertainties that may affect our business.

OVERVIEW OF OUR BUSINESS

IPALCO is a holding company incorporated under the laws of the state of Indiana. Our principal subsidiary is AES Indiana, a regulated electric utility operating in the state of Indiana. Substantially all of our business consists of the generation, transmission, distribution and sale of electric energy conducted through AES Indiana. Our business segments are “utility” and “all other.” For additional information regarding our business, see "Item 1. Business” of our 2020 Form 10-K.

EXECUTIVE SUMMARY

Compared with the same period in the prior year, the results for the three months ended June 30, 2021 reflect lower earnings from operations before income tax of $2.6 million or 10.6% primarily due to factors including, but not limited to:

•an increase in operation and maintenance expense primarily due to higher outage costs.

This was partially offset by:

•a net increase in margin due to higher volumes of retail kWh sold mostly due to higher weather-normalized demand resulting from unfavorable demand impacts of the COVID-19 pandemic in the prior year; and

•lower pension costs.

Compared with the same period in the prior year, the results for the six months ended June 30, 2021 reflect higher earnings from operations before income tax of $0.5 million, or 0.7%, primarily due to factors including, but not limited to:

•a net increase in margin due to higher volumes of retail kWh sold mostly due to favorable weather; and

•lower pension costs.

These were partially offset by:

•an increase in operation and maintenance expense primarily due to higher outage costs.

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RESULTS OF OPERATIONS

The electric utility business is affected by seasonal weather patterns throughout the year and, therefore, operating revenues and associated expenses are not generated evenly by month during the year. 

Statements of Operations Highlights

	Three Months Ended								Six Months Ended
	June 30,								June 30,
$ in Thousands	2021		2020		$ change		% change		2021		2020		$ change		% change
REVENUES	$	330,587	$	311,503	$	19,084	6.1	%	$	692,788	$	668,885	$	23,903	3.6	%
OPERATING COSTS AND EXPENSES:
Fuel	52,840		43,351		9,489		21.9	%	137,571		112,139		25,432		22.7	%
Power purchased	41,748		43,082		(1,334)		(3.1)	%	66,331		78,549		(12,218)		(15.6)	%
Operation and maintenance	116,381		94,659		21,722		22.9	%	220,330		200,248		20,082		10.0	%
Depreciation and amortization	62,994		61,099		1,895		3.1	%	126,083		121,807		4,276		3.5	%
Taxes other than income taxes	8,745		11,606		(2,861)		(24.7)	%	21,696		23,664		(1,968)		(8.3)	%
Total operating costs and expenses	282,708		253,797		28,911		11.4	%	572,011		536,407		35,604		6.6	%
OPERATING INCOME	47,879		57,706		(9,827)		(17.0)	%	120,777		132,478		(11,701)		(8.8)	%
OTHER INCOME / (EXPENSE), NET:
Allowance for equity funds used during construction	1,331		1,160		171		14.7	%	2,705		2,017		688		34.1	%
Interest expense	(32,199)		(33,935)		1,736		(5.1)	%	(62,266)		(64,016)		1,750		(2.7)	%
Loss on early extinguishment of debt	—		(2,415)		2,415		(100.0)	%	—		(2,415)		2,415		(100.0)	%
Other income, net	4,704		1,772		2,932		165.5	%	9,318		1,979		7,339		370.8	%
Total other expense, net	(26,164)		(33,418)		7,254		(21.7)	%	(50,243)		(62,435)		12,192		(19.5)	%
EARNINGS FROM OPERATIONS BEFORE INCOME TAX	21,715		24,288		(2,573)		(10.6)	%	70,534		70,043		491		0.7	%
Less: Income tax expense	4,505		5,165		(660)		(12.8)	%	14,540		14,937		(397)		(2.7)	%
NET INCOME	17,210		19,123		(1,913)		(10.0)	%	55,994		55,106		888		1.6	%
Less: Dividends on preferred stock	804		804		—		—	%	1,607		1,607		—		—	%
NET INCOME APPLICABLE TO COMMON STOCK	$	16,406	$	18,319	$	(1,913)	(10.4)	%	$	54,387	$	53,499	$	888	1.7	%

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Revenues

Revenues during the three and six months ended June 30, 2021 increased $19.1 million and $23.9 million, respectively, compared to the same periods in 2020, which resulted from the following changes (dollars in thousands):

	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2021		2020		$ Change		% Change	2021		2020		$ Change		% Change
Revenues:
Retail revenues	$	322,627	$	304,359	$	18,268	6.0%	$	665,059	$	647,147	$	17,912	2.8%
Wholesale revenues	4,918		4,501		417		9.3%	21,027		15,809		5,218		33.0%
Miscellaneous revenues	3,042		2,643		399		15.1%	6,702		5,929		773		13.0%
Total revenues	$	330,587	$	311,503	$	19,084	6.1%	$	692,788	$	668,885	$	23,903	3.6%
Heating degree days:
Actual	575		640		(65)		(10.2)%	3,279		3,074		205		6.7%
30-year average	532		531					3,290		3,290
Cooling degree days:
Actual	367		342		25		7.3%	367		342		25		7.3%
30-year average	312		310					312		310

The following table presents additional data on kWh sold:

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2021	2020	kWh Change	% Change		2021	2020	kWh Change	% Change
kWh Sales (In Millions):
Residential	1,080	1,109	(29)	(2.6)	%	2,609	2,531	78	3.1	%
Small commercial and industrial	400	367	33	9.0	%	883	843	40	4.7	%
Large commercial and industrial	1,494	1,381	113	8.2	%	2,874	2,818	56	2.0	%
Public lighting	5	6	(1)	(16.7)	%	11	16	(5)	(31.3)	%
Sales – retail customers	2,979	2,863	116	4.1	%	6,377	6,208	169	2.7	%
Wholesale	172	189	(17)	(9.0)	%	819	674	145	21.5	%
Total kWh sold	3,151	3,052	99	3.2	%	7,196	6,882	314	4.6	%

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The following graph shows the percentage changes in weather-normalized and actual retail electric sales volumes by customer class for the three months ended June 30, 2021 as compared to the same period in the prior year:

The following graph shows the percentage changes in weather-normalized and actual retail electric sales volumes by customer class for the six months ended June 30, 2021 as compared to the same period in the prior year:

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During the three months ended June 30, 2021, revenue increased $19.1 million to $330.6 million compared to $311.5 million in the same period of the prior year, and, during the six months ended June 30, 2021, revenue increased $23.9 million to $692.8 million compared to $668.9 million in the same period of the prior year. These changes were primarily the result of changes in the components of revenue shown below:

$ in millions		Three months ended June 30, 2021 vs. 2020		Six months ended June 30, 2021 vs. 2020
Retail revenues:
	Volume:
	Net increase in the volume of kWh sold, primarily due to higher weather-normalized demand during the three months ended June 30, 2021 attributable to the unfavorable demand impacts of the COVID-19 pandemic in the prior year and favorable weather in our service territory for the six months ended June 30, 2021 versus the comparable period	$	8.9	$	16.7
	Price:
	Net increase/(decrease) in the weighted average price of retail kWh sold, primarily due to higher fuel revenues during the three months ended June 30, 2021, including a higher reduction due to excess earnings under FAC provision in the prior period, and unfavorable block rate(1) and other retail rate variances for the three and six months ended June 30, 2021	5.1		(6.1)
	Other:
	Mostly due to increases in alternative revenue programs as a result of a favorable DSM shared savings true-up recorded in the current period	4.3		7.3
	Net change in retail revenues	18.3		17.9
Wholesale revenues:
	Volume:
	Net (decrease)/increase in the volume of wholesale kWh sold. The amount of electricity available for wholesale sales is impacted by our retail load requirements, generation capacity and unit availability.	(0.4)		3.4
	Price:
	Net increase in the weighted average price of wholesale kWh sold. Our ability to be dispatched in the MISO market is primarily driven by the locational marginal price of electricity and variable generation costs.	0.8		1.8
	Net change in wholesale revenues	0.4		5.2
Miscellaneous revenues		0.4		0.8
Net change in revenues		$	19.1	$	23.9

(1)Block rate variances are primarily attributable to our declining block rate structure, which generally provides for residential and commercial customers to be charged a lower per kWh rate at higher consumption levels. Therefore, as volumes increase, the weighted average price per kWh decreases and vice versa.

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Operating Costs and Expenses

The following table illustrates our changes in Operating costs and expenses during the three and six months ended June 30, 2021 compared to the same periods in 2020 (in thousands):

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2021		2020		$ Change		% Change		2021		2020		$ Change		% Change
Operating costs and expenses:
Fuel	$	52,840	$	43,351	$	9,489	21.9	%	$	137,571	$	112,139	$	25,432	22.7	%
Power purchased	41,748		43,082		(1,334)		(3.1)	%	66,331		78,549		(12,218)		(15.6)	%
Operation and maintenance	116,381		94,659		21,722		22.9	%	220,330		200,248		20,082		10.0	%
Depreciation and amortization	62,994		61,099		1,895		3.1	%	126,083		121,807		4,276		3.5	%
Taxes other than income taxes	8,745		11,606		(2,861)		(24.7)	%	21,696		23,664		(1,968)		(8.3)	%
Total operating costs and expenses	$	282,708	$	253,797	$	28,911	11.4	%	$	572,011	$	536,407	$	35,604	6.6	%

Fuel

The increases in fuel costs of $9.5 million and $25.4 million during the three and six months ended June 30, 2021, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions		Three months ended June 30, 2021 vs. 2020		Six months ended June 30, 2021 vs. 2020
Volume:
	Coal	$	31.2	$	48.6
	Natural gas	(17.6)		(23.7)
	Oil	0.4		0.3
	Net change in volume	14.0		25.2
Price:
	Coal	1.5		(0.9)
	Natural gas	7.9		29.7
	Oil	—		(0.1)
	Deferred fuel	(13.9)		(28.5)
	Net change in price	(4.5)		0.2
Net change in fuel expense		$	9.5	$	25.4

We are generally permitted to recover underestimated fuel and purchased power costs to serve our retail customers in future rates through quarterly FAC proceedings. These variances are deferred when incurred and amortized into expense in the same period that our rates are adjusted to reflect these variances. Additionally, fuel and purchased power costs incurred for wholesale energy sales are considered in the Off System Sales Margin rider.

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Power Purchased

The decreases in power purchased of $1.3 million and $12.2 million during the three and six months ended June 30, 2021, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions	Three months ended June 30, 2021 vs. 2020		Six months ended June 30, 2021 vs. 2020
Net change in the volume of power purchased primarily due to AES Indiana's generation units running more frequently during 2021, as well as the timing and duration of outages during these respective periods	$	(3.6)	$	(21.7)
Net change in the market price of power purchased	1.9		9.5
Other, net	0.4		—
Net change in power purchased costs	$	(1.3)	$	(12.2)

The volume of power purchased each period is primarily influenced by retail demand, generating unit capacity and outages, and the relative cost of producing power versus purchasing power in the market. The market price of purchased power is influenced primarily by changes in the market price of delivered fuel (primarily natural gas), the supply of and demand for electricity, and the time of day during which power is purchased.

Operation and Maintenance

The increases in Operation and maintenance of $21.7 million and $20.1 million during the three and six months ended June 30, 2021, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions	Three months ended June 30, 2021 vs. 2020		Six months ended June 30, 2021 vs. 2020
Increase in maintenance expenses primarily due to increased outage costs	$	11.7	$	7.2
Increase in compensation expenses, including wages, vacation, and other people expenses	2.0		3.2
Increase in charges from the Service Company	2.5		2.5
Increase in insurance expense and premiums	1.8		2.2
Increase in chemical expenses	1.9		1.9
Other, net	1.8		3.1
Net change in operation and maintenance costs	$	21.7	$	20.1

Depreciation and Amortization

The increases in Depreciation and amortization expense of $1.9 million and $4.3 million during the three and six months ended June 30, 2021, respectively, compared to the same periods of the prior year were mostly attributed to the impact of additional assets placed in service.

Taxes Other Than Income Taxes

The decreases in Taxes other than income taxes of $2.9 million and $2.0 million during the three and six months ended June 30, 2021, respectively, was mostly attributed to lower property taxes primarily as a result of lower assessed values.

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Other Income / (Expense), Net

The following table illustrates our changes in Other income / (expense), net during the three and six months ended June 30, 2021 compared to the same period in 2020 (in thousands):

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2021		2020		$ Change		% Change		2021		2020		$ Change		% Change
Other income/(expense), net
Allowance for equity funds used during construction	$	1,331	$	1,160	$	171	14.7	%	$	2,705	$	2,017	$	688	34.1	%
Interest expense	(32,199)		(33,935)		1,736		(5.1)	%	(62,266)		(64,016)		1,750		(2.7)	%
Loss on early extinguishment of debt	—		(2,415)		2,415		100.0	%	—		(2,415)		2,415		100.0	%
Other income, net	4,704		1,772		2,932		165.5	%	9,318		1,979		7,339		370.8	%
Total other income/(expense), net	$	(26,164)	$	(33,418)	$	7,254	(21.7)	%	$	(50,243)	$	(62,435)	$	12,192	(19.5)	%

Interest Expense

During the three months ended June 30, 2021, Interest expense decreased $1.7 million compared to the same period in the prior year primarily due to a lower average long-term debt balance during the period and increased capitalized interest.

During the six months ended June 30, 2021, Interest expense decreased $1.8 million compared to the same period in the prior year primarily due to increased capitalized interest and lower amortization of unrealized losses on interest rate hedges.

Loss on Early Extinguishment of Debt

The decreases in Loss on early extinguishment of debt of $2.4 million during the three and six months ended June 30, 2021, respectively, were primarily due to a make-whole premium and write-off of deferred financing costs due to the redemption of $405 million of 2020 IPALCO Notes and $65 million IPALCO Term Loan in the second quarter of 2020.

Other Income/(Expense), Net

The increases in Other income/(expense), net of $2.9 million and $7.3 million during the three and six months ended June 30, 2021, respectively, were primarily due to decreases in defined benefit plan costs of $3.5 million and $7.3 million, respectively, due to lower interest cost and a higher expected return on plan assets compared to the prior year.

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KEY TRENDS AND UNCERTAINTIES

During the remainder of 2021 and beyond, we expect that our financial results will be driven primarily by retail demand, weather and maintenance costs. In addition, our financial results will likely be driven by many other factors including, but not limited to:

•regulatory outcomes and impacts;

•the passage of new legislation, implementation of regulations or other changes in regulation; and

•timely recovery of capital expenditures.

If favorable outcomes related to these factors do not occur, or if the challenges described below and elsewhere in this Quarterly Report impact us more significantly than we currently anticipate, then these factors, or other factors unknown to us, may impact our operating margin, net income and cash flows. We continue to monitor our operations and address challenges as they arise. For a discussion of the risks related to our business, see “Item 1. Business” and “Item 1A. Risk Factors” as described in IPALCO’s 2020 Form 10-K.

COVID-19 Pandemic

The COVID-19 pandemic has impacted global economic activity, including electricity and energy consumption, and caused significant volatility in financial markets. Responses to the COVID-19 pandemic by the State of Indiana and its residents and businesses continue to evolve as vaccine availability and usage continues and the State and businesses review and adjust the scope and requirements of social distancing measures.

Social distancing measures designed to slow the spread of the virus, such as business closures and operations limitations, impact energy demand within our service industry. In addition to the impacts to demand within our service territory, we also have incurred and may continue to incur expenses relating to COVID-19, and such expenses may include those that relate to events outside of our control. We experienced impacts from the pandemic in 2020 and into 2021 and expect to continue to experience impacts for the remainder of 2021, and any such impacts during that time or in other future periods could have material and adverse effects on our results of operations, financial condition and cash flows. The following discussion highlights our assessment of the impacts of the COVID-19 pandemic on our current financial and operating status, and our financial and operational outlook based on information known as of this filing. Also see "Item 1A. Risk Factors" to IPALCO’s 2020 Form 10-K.

Business Continuity - During the COVID-19 pandemic, we are taking a variety of measures to ensure our ability to generate, transmit, distribute and sell electric energy, to ensure the health and safety of our employees, contractors, customers and communities and to provide essential services to the communities in which we operate. We continue to respond to this global crisis through comprehensive measures to protect our employees and others while fulfilling our vital role in providing our customers with electric energy. While stay-at-home restrictions have been lifted in our service territory, most of our management and administrative personnel are able to work remotely, and we have not experienced significant issues affecting our operations or ability to maintain effective internal controls and produce reliable financial information.

Demand - As the economic impact of the COVID-19 pandemic started to materialize in Indiana in the second half of March 2020 and continued for the duration of 2020 and into 2021, the COVID-19 pandemic primarily impacted our retail sales demand. Retail sales demand decreased in 2020 mostly from small and large commercial and industrial customers, but has started to recover in 2021 as shown by the changes in weather-normalized volumes of kWh sold by customer class as follows:

	For the three months ended						For the three months ended				For the six months ended
	March 31,				(2.9)	%	June 30,				June 30,
Customer Class	2021 vs. 2020		2020 vs. 2019		(2.9)	%	2021 vs. 2020		2020 vs. 2019		2021 vs. 2020		2020 vs. 2019
Residential	(0.9)	%	1.6	%	(2.9)	%	(3.3)	%	6.6	%	(1.9)	%	3.6	%
Small commercial and industrial	(1.8)	%	(1.8)	%	(2.9)	%	8.2	%	(10.3)	%	2.5	%	(5.6)	%
Large commercial and industrial	(4.1)	%	(2.8)	%	(3.9)	%	7.9	%	(11.0)	%	1.8	%	(7.0)	%
Total	(2.4)	%	(0.8)	%			3.6	%	(4.9)	%	0.3	%	(2.7)	%

As noted above, we also have incurred and may continue to incur expenses relating to COVID-19, however see Note 2, “Regulatory Matters - IURC COVID-19 Orders” to IPALCO’s 2020 Form 10-K for a discussion of regulatory measures which partially mitigate the impact of these expenses. While we have continued to experience COVID-19 impacts into 2021, we expect that such impacts would lessen as the scope and requirements of social distancing

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measures continue to be adjusted and energy demand improves. The magnitude and duration of the COVID-19 pandemic is unknown at this time and may have material and adverse effects on our results of operations, financial condition and cash flows in future periods.

Liquidity - We anticipate continuing to have sufficient liquidity to make all required payments, including payments for salaries and wages owed to our employees, during the COVID-19 pandemic. We also continue to not foresee a significant impact to our access to capital or our liquidity position as a result of the COVID-19 pandemic. For further discussion of our financial condition, liquidity, and capital requirements, see "Part I, Item 2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" of this Form 10-Q.

Credit Exposures - We continue to monitor and manage our credit exposures in a prudent manner. During the year ended December 31, 2020, we experienced credit-related impacts from utility customers due to the prohibition of electric utilities, including us, from discontinuing electric utility service to customers (prohibition ended August 14, 2020), and due to the economic impacts of the COVID-19 pandemic, which began to improve in 2021. See Note 1, "Overview and Summary of Significant Accounting Policies - Accounts Receivable" for further discussion of our allowance for credit losses. If these credit-related impacts from the COVID-19 pandemic continue into 2021 or beyond, further deterioration in our credit exposures and customer collections may result. See Note 2, “Regulatory Matters - IURC COVID-19 Orders” to IPALCO’s 2020 Form 10-K for a discussion of regulatory measures which mitigate this impact.

Supply Chain - Our supply chain management has remained robust during this challenging time and we continue to closely manage and monitor developments.

Capital Projects - During the COVID-19 pandemic, our construction projects are proceeding without material delays. For further discussion of our capital requirements, see "Part I, Item 2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" of this Form 10-Q.

CARES Act - The Coronavirus Aid, Relief, and Economic Security (“CARES”) Act was passed by the U.S. Congress and signed into law on March 27, 2020. While we currently expect a limited impact from this legislation on our business, we have deferred the payment of federal payroll taxes in accordance with the provisions of this act. At June 30, 2021, the total deferral was approximately $5.0 million.

See Note 12, "Risks and Uncertainties" to the Financial Statements of this Form 10-Q for more information.

Operational

As part of AES Indiana's December 2019 Integrated Resource Plan filing, AES Indiana retired 230 MW Petersburg Unit 1 on May 31, 2021 and has plans to retire 415 MW Petersburg Unit 2 in 2023. AES Indiana issued an all-source request for proposal to competitively procure replacement capacity by June 1, 2023, which is the first year AES Indiana is expected to have a capacity shortfall. Proposals were received through February 28, 2020 and are currently being evaluated. On February 5, 2021, AES Indiana announced an agreement to acquire a 195 MW solar project, expected to commence operations in 2023 and on June 16, 2021, AES Indiana received an order from the IURC approving the project. On August 2, 2021, AES Indiana announced plans to acquire a 250 MW solar and 180 MWh energy storage facility expected to commence operations in 2024, subject to approval from the IURC. For further discussion, see Note 2, "Regulatory Matters - IRP Filing and Replacement Generation" to the Financial Statements of this Form 10-Q and Note 2, "Regulatory Matters - IRP Filing" in IPALCO’s 2020 Form 10-K.

Regulatory and Environmental

Please see Note 2, "Regulatory Matters" to the Financial Statements of this Form 10-Q and Note 2, “Regulatory Matters” to IPALCO’s 2020 Form 10-K for a discussion of regulatory matters. We also are subject to numerous environmental laws and regulations in the jurisdictions in which we operate. We face certain risks and uncertainties related to these environmental laws and regulations, including existing and potential GHG legislation or regulations, and actual or potential laws and regulations pertaining to water discharges, waste management (including disposal or beneficial reuse of CCR) and certain air emissions, such as SO2, NOx, particulate matter and mercury. Such risks and uncertainties could result in increased capital expenditures or other compliance costs which could have a material adverse effect on our consolidated results of operations. Please see Note 8, “Commitments and Contingencies” to the Financial Statements of this Form 10-Q for a description of certain environmental matters. In

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addition, the following discussion of the impact of environmental laws and regulations on the Company updates the discussion provided in “Item 1. Business - Regulatory Matters” and “Item 1. Business - Environmental Matters” in IPALCO’s 2020 Form 10-K.

Climate Change Regulation

On August 31, 2018, the EPA published in the Federal Register proposed Emission Guidelines for Greenhouse Gas

Emissions from Existing Electric Utility Generating Units, known as the ACE Rule. On July 8, 2019, the EPA

published the final ACE Rule along with associated revisions to implementing regulations. The final ACE Rule

established CO2 emission rules for existing power plants under CAA Section 111(d) and replaced the EPA's 2015

CPP. In accordance with the ACE rule, the EPA determined that heat rate improvement measures are the Best

System of Emissions Reductions for existing coal-fired electric generating units. The final rule required the State of

Indiana to develop a State Plan to establish CO2 emission limits for designated facilities, including AES Indiana Petersburg's coal-fired electric generating units. States had three years to develop their plans under the rule. However, on January 19, 2021, the D.C. Circuit vacated and remanded to EPA the ACE Rule, but withheld issuance of the mandate that would effectuate its decision. On February 22, 2021, the D.C. Circuit granted EPA’s unopposed motion for a partial stay of the issuance of the mandate on vacating the repeal of the CPP. On March 5, 2021, the D.C. Circuit issued the partial mandate effectuating the vacatur of the ACE Rule. In effect, the CPP will not take effect while EPA is addressing the remand of the ACE rule by promulgating a new Section 111(d) rule to regulate greenhouse gases from existing electric generating units. The impact of such future greenhouse gas emissions regulations remains uncertain, but it could be material.

CSAPR

CSAPR, which became effective in January 2015, addresses the "good neighbor" provision of the CAA, which

prohibits sources within each state from emitting any air pollutant in an amount which will contribute significantly to any other state’s nonattainment, or interference with maintenance of, any NAAQS. The CSAPR is implemented, in

part, through a market-based program under which compliance may be achievable through the acquisition and use

of emissions allowances created by the EPA. In October 2016, the EPA published a final rule to update the CSAPR

to address the 2008 ozone NAAQS (“CSAPR Update Rule”). The CSAPR Update Rule found that NOx ozone

season emissions in 22 states (including Indiana) affect the ability of downwind states to attain and maintain the

2008 ozone NAAQS, and accordingly, the EPA issued federal implementation plans that both generally provide

updated CSAPR NOx ozone season emission budgets for electric generating units within these states and that

implement these budgets through modifications to the CSAPR NOx ozone season allowance trading program.

Implementation began in the 2017 ozone season (May through September 2017). Affected facilities receive fewer

ozone season NOx allowances in 2017 and later, possibly resulting in the need to purchase additional allowances.

Additionally, on September 13, 2019, the D.C. Circuit remanded a portion of the October 2016 CSAPR Update Rule

to the EPA. In December 2018, EPA determined that the 2016 CSAPR Update Rule fully satisfied 20 states

(including Indiana) good neighbor obligations with respect to the 2008 Ozone NAAQS (“CSAPR Close-Out Rule”),

obviating the need for EPA to promulgate Federal Implementation Plans (FIPs) in these states. In October 2019, the

D.C. Circuit vacated and remanded the CSAPR Close-Out Rule. On July 28, 2020, the D.C. Circuit ordered EPA to

issue FIPs addressing seven states’ (including Indiana) outstanding 2008 NAAQS “good neighbor” obligations by

March 15, 2021. On April 30, 2021, EPA published a final rule to address the 2020 D.C. Circuit decision. EPA is issuing new or amended federal implementation plans for 12 states, including Indiana, with revised CSAPR NOx ozone season emission budgets for electric generating units within these states via a new CSAPR NOx Ozone Season Group 3 Trading Program. Implementation began during the 2021 ozone season (May through September 2021) with an effective date of June 29, 2021. AES Indiana facilities will receive fewer ozone season NOx allowances for future NOx Ozone Seasons beginning in 2021 and later, possibly resulting in the need to purchase additional allowances.

At this time we cannot predict what the impact of these rule revisions or potential future legal outcomes, but any such impact could be material to our business, financial condition or results of operation.

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Macroeconomic and Political

Reference Rate Reform

As discussed in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations—Key Trends and Uncertainties" of IPALCO's 2020 Form 10-K, in July 2017, the UK Financial Conduct Authority announced that it intends to phase out LIBOR by the end of 2021. In the U.S., the Alternative Reference Rate Committee at the Federal Reserve identified the Secured Overnight Financing Rate ("SOFR") as its preferred alternative rate for LIBOR; alternative reference rates in other key markets are under development. The ICE Benchmark Association ("IBA") has determined that it will cease publication of one week and two month LIBOR rates by December 31, 2021, and will cease publication of the one-month, three-month, six-month, and 12-month USD LIBOR rates by June 30, 2023. We maintain financial instruments that use LIBOR as an interest rate benchmark and will continue to engage with counterparties to make this transition.

CAPITAL RESOURCES AND LIQUIDITY

Overview

As of June 30, 2021, we had unrestricted cash and cash equivalents of $20.6 million and available borrowing capacity of $150 million under our unsecured revolving Credit Agreement. All of AES Indiana’s long-term borrowings must first be approved by the IURC and the aggregate amount of AES Indiana’s short-term indebtedness must be approved by the FERC. We have approval from the FERC to borrow up to $500 million of short-term indebtedness outstanding at any time through July 26, 2022. In December 2018, we received an order from the IURC granting us authority through December 31, 2021 to, among other things, issue up to $350 million in aggregate principal amount of long-term debt, all of which authority remains available under the order as of June 30, 2021, and refinance up to $185 million in existing indebtedness, of which $95 million of authority remains available under the order as of June 30, 2021 and no authority remains following the July 2021 issuance of AES Indiana first mortgage bonds (see Note 5, “Debt - AES Indiana First Mortgage Bonds”). This order also grants us authority to have up to $500 million of long-term credit agreements and liquidity facilities outstanding at any one time, of which $250 million remains available under the order as of June 30, 2021. As an alternative to the sale of all or a portion of $65 million in principal of the long-term debt, we have the authority to issue up to $65 million of new preferred stock, all of which authority remains available under the order as of June 30, 2021. We also have restrictions on the amount of new debt that may be issued due to contractual obligations of AES and by financial covenant restrictions under our existing debt obligations. We do not believe such restrictions will be a limiting factor in our ability to issue debt in the ordinary course of prudent business operations.

We believe that existing cash balances, cash generated from operating activities, and borrowing capacity on our committed Credit Agreement will be adequate for the foreseeable future to meet anticipated operating expenses, interest expense on outstanding indebtedness, recurring capital expenditures, and to pay dividends to AES U.S. Investments and CDPQ. Sources for principal payments on outstanding indebtedness and nonrecurring capital expenditures are expected to be obtained from: (i) existing cash balances; (ii) cash generated from operating activities; (iii) borrowing capacity on our committed Credit Agreement; (iv) additional debt financing; and (v) equity capital contributions. From time to time, we may elect to repurchase our outstanding debt through cash purchases, privately negotiated transactions or otherwise when management believes such repurchases are favorable to make. The amounts involved in any such repurchases may be material.

AES Indiana First Mortgage Bonds

In July 2021, the Indiana Finance Authority issued on behalf of AES Indiana an aggregate principal amount of $95 million of Environmental Facilities Refunding Revenue Bonds, Series 2021A&B. For further discussion, please see Note 5, “Debt - AES Indiana First Mortgage Bonds.”

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Cash Flows

The following table provides a summary of our cash flows (in thousands):

	Six Months Ended June 30,
	2021		2020		$ Change
Net cash provided by operating activities	$	179,099	$	146,323	$	32,776
Net cash used in investing activities	(145,491)		(113,441)		(32,050)
Net cash used in financing activities	(39,596)		(28,183)		(11,413)
Net change in cash and cash equivalents	(5,988)		4,699		(10,687)
Cash, cash equivalents and restricted cash at beginning of period	26,622		48,552		(21,930)
Cash, cash equivalents and restricted cash at end of period	$	20,634	$	53,251	$	(32,617)

Operating Activities

The following table summarizes the key components of our consolidated operating cash flows (in thousands):

	Six Months Ended June 30,
	2021		2020		$ Change
Net income	$	55,994	$	55,106	$	888
Depreciation and amortization	126,083		121,807		4,276
Deferred income taxes and investment tax credit adjustments - net	5,866		860		5,006
Other adjustments to net income	(728)		2,485		(3,213)
Net income, adjusted for non-cash items	187,215		180,258		6,957
Net change in operating assets and liabilities(1)	(8,116)		(33,935)		25,819
Net cash provided by operating activities	$	179,099	$	146,323	$	32,776
(1) Refer to the table below for explanations of the variance in operating assets and liabilities.

The net change in operating assets and liabilities for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 was driven by changes in the following (in thousands):

Increase from accounts payable is primarily due to timing of payments	$	38,712
Increase from inventories primarily due to higher coal consumption in 2021	33,246
Decrease from short-term and long-term regulatory assets and liabilities is primarily due to higher deferred fuel expense in 2021	(20,227)
Decrease from accrued taxes payable/receivables is primarily due to timing of property tax and utility receipts tax payments, partially offset by lower tax sharing payments	(17,591)
Decrease from prepayments and other current assets is primarily due to increased payments to Service Company in 2021	(9,357)
Other	1,036
Net change in operating assets and liabilities	$	25,819

Investing Activities

Net cash used in investing activities increased $32.1 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020, which was primarily driven by (in thousands):

Higher cash outflows for capital expenditures due to higher growth related capital expenditures primarily from TDSIC Plan investments, partially offset by lower maintenance and environmental related capital expenditures	$	(39,457)
Lower cash outflows on cost of removal and regulatory recoverable ARO payments due to timing of such payments	6,926
Other	481
Net change in investing activities	$	(32,050)

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Financing Activities

Net cash used in financing activities increased $11.4 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020, which was primarily driven by (in thousands):

Higher distributions to shareholders	$	(9,352)
Decrease from net borrowings under revolving credit facilities due to lower net draws on AES Indiana's line of credit in 2021	(5,000)
Increase from lower deferred financing costs paid in 2021	5,384
Other	(2,445)
Net change in financing activities	$	(11,413)

Capital Requirements

Capital Expenditures

Our capital expenditure program, including development and permitting costs, for the three-year period from 2021 through 2023 (including amounts already expended in the first six months of 2021) is currently estimated to cost approximately $1.5 billion (excluding environmental compliance), and includes estimates as follows (amounts in millions):

							For the three-year period
	2021		2022		2023		from 2021 through 2023
Transmission and distribution related additions, improvements and extensions	$	287	$	268	$	287	$	842	(1)
Power generation related projects	55		266		222		543
Other miscellaneous equipment	63		53		35		151
Total estimated costs of capital expenditure program	$	405	$	587	$	544	$	1,536
(1) Additions, improvements and extensions to transmission and distribution lines, substations, power factor and voltage regulating equipment, distribution transformers and street lighting facilities

The amounts described in the capital expenditure program above include spending under AES Indiana's TDSIC plan approved by the IURC on March 4, 2020 for eligible transmission, distribution and storage system improvements totaling $1.2 billion from 2020 through 2027 (which includes estimated spending of $176.5 million in 2021, $190.0 million in 2022 and $212.6 million in 2023, respectively). Total TDSIC costs expended from project inception through June 30, 2021 were $217.9 million.

Additionally, estimated capital expenditure spending on environmental compliance costs for the three-year period from 2021 through 2023 includes the following (amounts in millions):

	Total Estimated Costs		Total Costs Expended		Remaining Costs
	of Project		Through June 30, 2021		of Project
NAAQS SO2 (1)	$	27	$	27	$	—
Cooling water intake regulations (2)	$	9	$	2	$	7
(1) Includes spending for projects underway related to environmental compliance for NAAQS SO2.
(2) Includes spending for studies related to cooling water intake requirements in section 316(b) of the CWA.

Please see “Item 1. Business - Environmental Matters" in IPALCO’s 2020 Form 10-K for additional details on each of these projects.

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Credit Ratings

Our ability to borrow money or to refinance existing indebtedness and the interest rates at which we can borrow money or refinance existing indebtedness are affected by our credit ratings. In addition, the applicable interest rates on AES Indiana’s Credit Agreement (as well as the amount of certain other fees in the Credit Agreement) are dependent upon the credit ratings of AES Indiana. Downgrades in the credit ratings of AES could result in AES Indiana’s and/or IPALCO’s credit ratings being downgraded. Any reduction in our debt or credit ratings may adversely affect the trading price of our outstanding debt securities.

The following table presents the debt ratings and credit ratings (issuer/corporate rating) and outlook for IPALCO and AES Indiana.

Debt ratings	IPALCO	AES Indiana	Outlook
Fitch Ratings	BBB (a)	A (b)	Stable
Moody’s Investors Service	Baa3 (a)	A2 (b)	Stable
S&P Global Ratings	BBB- (a)	A- (b)	Positive
Credit ratings	IPALCO	AES Indiana	Outlook
Fitch Ratings	BBB-	BBB+	Stable
Moody’s Investors Service	—	Baa1	Stable
S&P Global Ratings	BBB	BBB	Positive

(a)Ratings relate to IPALCO’s Senior Secured Notes.

(b)Ratings relate to AES Indiana first mortgage bonds.

We cannot predict whether our current debt and credit ratings or the debt and credit ratings of AES Indiana will remain in effect for any given period of time or that one or more of these ratings will not be lowered or withdrawn entirely by a rating agency. A security rating is not a recommendation to buy, sell or hold securities. Such ratings may be subject to revision or withdrawal at any time by the assigning rating organization, and each rating should be evaluated independently of any other rating.

Dividend Distributions

All of IPALCO’s outstanding common stock is held by AES U.S. Investments and CDPQ. During the first six months of 2021 and 2020, IPALCO paid $62.6 million and $53.2 million, respectively, in distributions to its shareholders. Future distributions to our shareholders will be determined at the discretion of our Board of Directors and will depend primarily on dividends received from AES Indiana. Dividends from AES Indiana are affected by AES Indiana’s actual results of operations, financial condition, cash flows, capital requirements, regulatory considerations, and such other factors as AES Indiana’s Board of Directors deems relevant.

Critical Accounting Policies and Estimates

The condensed consolidated financial statements of IPALCO are prepared in conformity with U.S. GAAP, which requires the use of estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the periods presented.

The Company’s significant accounting policies are described in Note 1, "Overview and Summary of Significant Accounting Policies" of our 2020 Form 10-K. The Company’s critical accounting estimates are described in "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations" in the 2020 Form 10-K. An accounting estimate is considered critical if the estimate requires management to make an assumption about matters that were highly uncertain at the time the estimate was made, different estimates reasonably could have been used, or if changes in the estimate that would have a material impact on the Company’s financial condition or results of operations are reasonably likely to occur from period to period. Management believes that the accounting estimates employed are appropriate and resulting balances are reasonable; however, actual results could differ from the original estimates, requiring adjustments to these balances in future periods. The Company has reviewed and determined that these remain as critical accounting policies as of and for the six months ended June 30, 2021.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK 

There have been no material changes to our quantitative and qualitative disclosure about market risk as previously disclosed in the 2020 Form 10-K.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures — The Company, under the supervision and with the participation of its management, including the Company’s Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), evaluated the effectiveness of its “disclosure controls and procedures,” as such term is defined in Rule 13a-15(e) under the Exchange Act, as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, our CEO and CFO have concluded that our disclosure controls and procedures were effective as of June 30, 2021, to ensure that information required to be disclosed by the Company in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and include controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosures.

Changes in Internal Controls over Financial Reporting — There were no changes that occurred during the fiscal quarter covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

In the normal course of business, we are subject to various lawsuits, actions, claims, and other proceedings. We are also from time to time involved in other reviews, investigations and proceedings by governmental and regulatory agencies regarding our business, certain of which may result in adverse judgments, settlements, fines, penalties, injunctions or other relief. We have accrued in our Financial Statements for litigation and claims where it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. We believe the amounts provided in our Financial Statements, as prescribed by GAAP, for these matters are adequate in light of the probable and estimable contingencies. However, there can be no assurances that the actual amounts required to satisfy alleged liabilities from various legal proceedings, claims and other matters (including those matters noted below), and to comply with applicable laws and regulations will not exceed the amounts reflected in our Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided for in our Financial Statements cannot be reasonably determined, but could be material.

Please see Note 7, “Commitments and Contingencies” to the Financial Statements included in Part I - Financial Information of this Form 10-Q for a summary of certain legal proceedings involving us. In addition, our Form 10-K for the fiscal year ended December 31, 2020 and the Notes to IPALCO's Consolidated Financial Statements included therein contain descriptions of certain legal proceedings in which we are or were involved. The information in or incorporated by reference into this Item 1 to Part II is limited to certain recent developments concerning our legal proceedings and new legal proceedings, since the filing of such Form 10-K, and should be read in conjunction with such Form 10-K and Form 10-Q.

ITEM 1A.  RISK FACTORS

There have been no material changes to the risk factors as previously disclosed in the 2020 Form 10-K.

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

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None. 

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ITEM 4.  MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.  OTHER INFORMATION

None.

ITEM 6. EXHIBITS

Exhibit No.	Document
31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
4.1	Sixty-ninth Supplemental Indenture, dated as of July 1, 2021
4.2	Seventieth Supplemental Indenture, dated as of July 1, 2021
101.INS	XBRL Instance Document (filed herewith as provided in Rule 406T of Regulation S-T)
101.SCH	XBRL Taxonomy Extension Schema Document (filed herewith as provided in Rule 406T of Regulation S-T)
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document (filed herewith as provided in Rule 406T of Regulation S-T)
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document (filed herewith as provided in Rule 406T of Regulation S-T)
101.LAB	XBRL Taxonomy Extension Label Linkbase Document (filed herewith as provided in Rule 406T of Regulation S-T)
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document (filed herewith as provided in Rule 406T of Regulation S-T)

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		IPALCO ENTERPRISES, INC.
Date:	August 4, 2021	/s/ Gustavo Garavaglia
		Gustavo Garavaglia
		Vice President and Chief Financial Officer
		(Principal Financial Officer)
Date:	August 4, 2021	/s/ Jon S. Byers
		Jon S. Byers
		Controller
		(Principal Accounting Officer)

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