ThZeal - The Zeal

cik0000728391-20220630

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, 2022

☐ 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 is a voluntary filer. 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, 2022, 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, 2022

TABLE OF CONTENTS


Item No.		Page No.
	GLOSSARY OF TERMS	4

	FORWARD-LOOKING STATEMENTS	5

	PART I - FINANCIAL INFORMATION
1.	Financial Statements (Unaudited)
	Condensed Consolidated Statements of Operations	7
	Condensed Consolidated Statements of Comprehensive Income/(Loss)	8
	Condensed Consolidated Balance Sheets	9
	Condensed Consolidated Statements of Cash Flows	10
	Condensed Consolidated Statements of Common Shareholders' Equity and Cumulative Preferred Stock of Subsidiary	11
	Notes to Condensed Consolidated Financial Statements	12
	Note 1 - Overview and Summary of Significant Accounting Policies	12
	Note 2 - Regulatory Matters	15
	Note 3 - Fair Value	16
	Note 4 - Derivative Instruments and Hedging Activities	18
	Note 5 - Debt	20
	Note 6 - Income Taxes	21
	Note 7 - Benefit Plans	21
	Note 8 - Commitments and Contingencies	22
	Note 9 - Business Segment Information	23
	Note 10 - Revenue	24
	Note 11 - Leases	26
	Note 12 - Risks and Uncertainties	26
2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27
3.	Quantitative and Qualitative Disclosure About Market Risk	42
4.	Controls and Procedures	42

	PART II - OTHER INFORMATION
1.	Legal Proceedings	43
1A.	Risk Factors	43
2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
3.	Defaults Upon Senior Securities	44
4.	Mine Safety Disclosures	44
5.	Other Information	44
6.	Exhibits	44

	SIGNATURES	45


GLOSSARY OF TERMS
The following is a list of frequently used terms, abbreviations or acronyms that are found in this Form 10-Q:

2021 Form 10-K			IPALCO’s Annual Report on Form 10-K for the year ended December 31, 2021, as amended
2024 IPALCO Notes			$405 million of 3.70% IPALCO Enterprises, Inc. Senior Secured Notes due September 1, 2024
2030 IPALCO Notes			$475 million of 4.25% IPALCO Enterprises, Inc. Senior Secured Notes due May 1, 2030
ACE			Affordable Clean Energy
AES			The AES Corporation
AES Indiana			Indianapolis Power & Light Company and its consolidated subsidiaries, which does business as AES Indiana
AES U.S. Investments			AES U.S. Investments, Inc.
AOCI			Accumulated Other Comprehensive Income
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 resulted in a global pandemic beginning in 2020.
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
EDG			Excess Distributed Generation
EGUs			Electrical Generating Units
EPA			U.S. Environmental Protection Agency
FAC			Fuel Adjustment Clause
FASB			Financial Accounting Standards Board
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
FIP			Federal Implementation Plan
FRP			Facility Response Plan
FTRs			Financial Transmission Rights
GAAP			Generally Accepted Accounting Principles in the United States
GHG			Greenhouse Gas
IBOR			Interbank Offered Rate
IDEM			Indiana Department of Environmental Management
IPALCO			IPALCO Enterprises, Inc. and its consolidated subsidiaries
IPL			Indianapolis Power & Light Company and its consolidated subsidiaries, 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 AES Indiana and Supplemental Retirement Plan of AES Indiana
PSD			Prevention of Significant Deterioration
SEC			United States Securities and Exchange Commission
SIP			State Implementation Plan
SO2			Sulfur Dioxide
TDSIC			Transmission, Distribution, and Storage System Improvement Charge
Term Loan Agreement			$200 million AES Indiana Term Loan Agreement, dated as of June 23, 2022
URT			Utility Receipts Tax
U.S.			United States of America
USD			United States Dollars
VEBA			Voluntary Employees' Beneficiary Association

Throughout this document, the terms "IPALCO," “the Company,” “we,” “us,” and “our” refer to IPALCO Enterprises, Inc. and its consolidated subsidiaries. The term “IPALCO Enterprises, Inc.” refers only to the parent holding company, IPALCO Enterprises, Inc, excluding its 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, distribution and generation 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 and climate change matters, including costs of compliance with, and liabilities related to, current and future environmental and climate change 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 Enterprises, Inc.;

•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 or other projects;

•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;

•costs and effects of legal and administrative proceedings, audits, settlements, investigations and claims and the ultimate disposition of litigation; cyber-attacks and information security breaches;

•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

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

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

Forward-looking statements speak only as of the date of the document in which they are made. We disclaim any obligation or undertaking to provide any updates or revisions to any forward-looking statement to reflect any change in our expectations or any change in events, conditions or circumstances on which the forward-looking statement is based. If we do update one or more forward-looking statements, no inference should be made that we will make additional updates with respect to those or other forward-looking statements.

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” in IPALCO’s 2021 Annual Report on Form 10-K and "Item 1A. Risk Factors" to Part II of this Quarterly Report on Form 10-Q and the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section in IPALCO’s 2021 Annual Report on Form 10-K and in IPALCO's Quarterly Report on Form 10-Q for the quarter ended March 31, 2022 and this Quarterly Report on Form 10-Q 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 other 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.

Our SEC filings are available to the public from the SEC’s website at www.sec.gov.

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS


IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Operations
(Unaudited)
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
	(In Thousands)
REVENUES	$	389,614	$	330,587	$	813,725	$	692,788

OPERATING COSTS AND EXPENSES:
Fuel	99,918		52,840		204,060		137,571
Power purchased	46,620		41,748		94,505		66,331
Operation and maintenance	139,543		116,381		250,556		220,330
Depreciation and amortization	66,266		62,994		132,286		126,083
Taxes other than income taxes	10,557		8,745		22,316		21,696
Other, net	—		—		(3,201)		—
Total operating costs and expenses	362,904		282,708		700,522		572,011

OPERATING INCOME	26,710		47,879		113,203		120,777

OTHER INCOME / (EXPENSE), NET:
Allowance for equity funds used during construction	1,686		1,331		3,374		2,705
Interest expense	(32,220)		(32,199)		(63,922)		(62,266)

Other income, net	2,631		4,704		5,838		9,318
Total other expense, net	(27,903)		(26,164)		(54,710)		(50,243)

(LOSS) / INCOME FROM OPERATIONS BEFORE INCOME TAX	(1,193)		21,715		58,493		70,534

Income tax (benefit) / expense	(241)		4,505		12,254		14,540
NET (LOSS) / INCOME	(952)		17,210		46,239		55,994

Less: Dividends on preferred stock	804		804		1,607		1,607
NET (LOSS) / INCOME APPLICABLE TO COMMON STOCK	$	(1,756)	$	16,406	$	44,632	$	54,387

See Notes to Condensed Consolidated Financial Statements.


IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Comprehensive Income/(Loss)
(Unaudited)
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
	(In Thousands)
Net (loss) / income applicable to common stock	$	(1,756)	$	16,406	$	44,632	$	54,387

Derivative activity:
Change in derivative fair value, net of income tax effect of $(6,265), $5,361, $(11,418) and $(4,294), for each respective period	18,925		(17,143)		34,490		12,907
Reclassification to earnings, net of income tax effect of $(449), $(431), $(898) and $(284), for each respective period	1,358		1,376		2,716		920
Net change in fair value of derivatives	20,283		(15,767)		37,206		13,827

Other comprehensive income (loss)	20,283		(15,767)		37,206		13,827

Net comprehensive income	$	18,527	$	639	$	81,838	$	68,214

See Notes to Condensed Consolidated Financial Statements.


IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Balance Sheets
(Unaudited)
	June 30,		December 31,
	2022		2021
	(In Thousands)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	16,826	$	6,912
Restricted cash	5		5
Accounts receivable, net of allowance for credit losses of $579 and $647, respectively	185,808		179,136
Inventories	116,449		101,899
Regulatory assets, current	153,273		63,813
Taxes receivable	17,613		15,566
Prepayments and other current assets	53,165		40,168
Total current assets	543,139		407,499
NON-CURRENT ASSETS:
Property, plant and equipment	6,809,827		6,643,929
Less: Accumulated depreciation	2,982,464		2,895,881
	3,827,363		3,748,048
Construction work in progress	256,770		210,297
Total net property, plant and equipment	4,084,133		3,958,345
OTHER NON-CURRENT ASSETS:
Intangible assets - net	114,414		106,316
Regulatory assets, non-current	619,398		656,977
Pension plan assets	53,440		49,182
Other non-current assets	66,089		61,448
Total other non-current assets	853,341		873,923
TOTAL ASSETS	$	5,480,613	$	5,239,767
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES:
Short-term debt and current portion of long-term debt (see Notes 5 and 11)	$	269,846	$	60,294
Accounts payable	209,257		179,834
Accrued taxes	24,086		25,898
Accrued interest	30,951		30,634
Customer deposits	34,110		28,916
Regulatory liabilities, current	15,988		4,241

Accrued and other current liabilities	15,747		18,696
Total current liabilities	599,985		348,513
NON-CURRENT LIABILITIES:
Long-term debt (see Notes 5 and 11)	2,669,745		2,671,656
Deferred income tax liabilities	302,339		290,727

Regulatory liabilities, non-current	822,259		826,709
Accrued other postretirement benefits	4,233		4,290
Asset retirement obligations	210,930		189,509
Derivative liabilities, non-current	3,473		49,382
Other non-current liabilities	1,303		4,597
Total non-current liabilities	4,014,282		4,036,870
Total liabilities	4,614,267		4,385,383
COMMITMENTS AND CONTINGENCIES (see Note 8)
SHAREHOLDERS' EQUITY:
Paid in capital	823,321		848,565
Accumulated other comprehensive income / (loss)	7,799		(29,407)
Accumulated deficit	(24,558)		(24,558)
Total common shareholders' equity	806,562		794,600
Preferred stock of subsidiary	59,784		59,784
Total shareholders' equity	866,346		854,384
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$	5,480,613	$	5,239,767

See Notes to Condensed Consolidated Financial Statements.


IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(Unaudited)
	Six Months Ended
	June 30,
	2022		2021
	(In Thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	46,239	$	55,994
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	132,286		126,083
Amortization of deferred financing costs and debt discounts	1,991		1,977
Deferred income taxes and investment tax credit adjustments - net	(6,799)		5,866
Allowance for equity funds used during construction	(3,374)		(2,705)

Change in certain assets and liabilities:
Accounts receivable	(6,672)		6,231
Inventories	(21,092)		9,900
Accounts payable	48,628		22,316
Accrued and other current liabilities	2,277		(3,934)
Accrued taxes payable/receivable	(3,859)		3,553
Accrued interest	317		52
Pension and other postretirement benefit assets and liabilities	(4,314)		(8,284)
Short-term and long-term regulatory assets and liabilities	(43,518)		(21,026)
Prepayments and other current assets	(12,997)		(12,526)


Other - net	1,356		(4,398)
Net cash provided by operating activities	130,469		179,099
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(228,840)		(132,305)
Project development costs	(976)		(624)
Cost of removal and regulatory recoverable ARO payments	(28,911)		(12,562)


Net cash used in investing activities	(258,727)		(145,491)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under revolving credit facilities	210,000		100,000
Repayments under revolving credit facilities	(200,000)		(75,000)
Short-term borrowings	200,000		—

Distributions to shareholders	(69,929)		(62,579)
Preferred dividends of subsidiary	(1,607)		(1,607)
Deferred financing costs paid	(259)		(280)
Payments for financed capital expenditures	—		(36)
Other	(33)		(94)
Net cash provided by (used in) financing activities	138,172		(39,596)
Net change in cash, cash equivalents and restricted cash	9,914		(5,988)
Cash, cash equivalents and restricted cash at beginning of period	6,917		26,622
Cash, cash equivalents and restricted cash at end of period	$	16,831	$	20,634

Supplemental disclosures of cash flow information:
Cash paid during the period for:
Interest (net of amount capitalized)	$	57,920	$	59,195
Income taxes	21,100		5,000
Non-cash investing activities:
Accruals for capital expenditures	$	61,912	$	56,465

See Notes to Condensed Consolidated Financial Statements.


IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Common Shareholders' Equity
and Cumulative Preferred Stock of Subsidiary
For the Three and Six Months Ended June 30, 2022 and 2021
(Unaudited)
	Paid in Capital		Accumulated Other Comprehensive Income (Loss)		Accumulated Deficit		Total Common Shareholders' Equity		Cumulative Preferred Stock of Subsidiary
	(In Thousands)
2022
Beginning Balance	$	848,565	$	(29,407)	$	(24,558)	$	794,600	$	59,784
Net comprehensive income	—		16,923		46,388		63,311		803
Preferred stock dividends	—		—		—		—		(803)
Distributions to shareholders	—		—		(35,805)		(35,805)		—
Other	26		—		—		26		—
Balance at March 31, 2022	$	848,591	$	(12,484)	$	(13,975)	$	822,132	$	59,784
Net comprehensive income/(loss)	—		20,283		(1,756)		18,527		804
Preferred stock dividends	—		—		—		—		(804)
Distributions to shareholders(1)	(25,297)		—		(8,827)		(34,124)		—
Other	27		—		—		27		—
Balance at June 30, 2022	$	823,321	$	7,799	$	(24,558)	$	806,562	$	59,784






2021
Beginning Balance	$	588,966	$	(43,420)	$	(24,558)	$	520,988	$	59,784
Net comprehensive income	—		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






(1) IPALCO made return of capital payments of $25.3 million and $8.2 million during the three months ended June 30, 2022 and 2021, respectively, for the portion of current year distributions to shareholders in excess of current year net income.

See Notes to Condensed Consolidated Financial Statements.

IPALCO ENTERPRISES, INC. and SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Three and Six Months Ended June 30, 2022 and 2021

(Unaudited)

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 517,000 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 four 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, which would result in 630 MW of total retired economic capacity at this station. 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, 2022, AES Indiana’s net electric generation capacity for winter is 3,475 MW and net summer capacity is 3,330 MW. On December 17, 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 1, LLC, completed the acquisition of Hardy Hills Solar Energy LLC, including the development of a 195 MW solar project (the "Hardy Hills Solar Project") expected to be completed in 2023. In July 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 2, LLC, executed an agreement to acquire a 250 MW solar and 180 MWh energy storage facility (the "Petersburg Solar Project") expected to be completed in 2024.

Consolidation

The accompanying Financial Statements include the accounts of IPALCO Enterprises, Inc., 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 unaudited condensed consolidated financial statements and footnotes 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 results of operations for the three and six months ended June 30, 2022 are not necessarily indicative of expected results for the year ending December 31, 2022. The accompanying condensed consolidated financial statements are unaudited and should be read in conjunction with the 2021 audited consolidated financial statements and notes thereto, which are included in the 2021 Form 10-K.

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. Significant items subject to such estimates and assumptions include: recognition of revenue including unbilled revenues; the carrying value of property, plant and equipment; the valuation of insurance and claims liabilities; the valuation of allowances for credit losses and deferred income taxes;

regulatory assets and liabilities; liabilities recorded for income tax exposures; litigation; contingencies; and assets and liabilities related to employee benefits.

Cash, Cash Equivalents and Restricted Cash

The following table provides a summary of cash, cash equivalents and restricted cash amounts reported on the Condensed Consolidated Balance Sheets that reconcile to the total of such amounts as shown on the Condensed Consolidated Statements of Cash Flows:


	June 30,		December 31,
	2022		2021
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	16,826	$	6,912
Restricted cash	5		5
Total cash, cash equivalents and restricted cash	$	16,831	$	6,917

Accounts Receivable

The following table summarizes our accounts receivable balances at June 30, 2022 and December 31, 2021:


	June 30,		December 31,
	2022		2021
	(In Thousands)
Accounts receivable, net
Customer receivables	$	105,650	$	100,952
Unbilled revenue	67,442		64,758
Amounts due from affiliates	370		169

Other	12,925		13,904
Allowance for credit losses	(579)		(647)
Total accounts receivable, net	$	185,808	$	179,136

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the six months ended June 30, 2022 and 2021, respectively:


$ in Thousands	Beginning Allowance Balance		Current Period Provision		Write-offs Charged Against Allowances		Recoveries Collected		Ending Allowance Balance
2022	$	647	$	2,492	$	(3,362)	$	802	$	579
2021	$	3,155	$	1,030	$	(3,741)	$	1,109	$	1,553

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, 2022. Amounts are written off when reasonable collections efforts have been exhausted. During the six months ended June 30, 2021, the current period provision and allowance for credit losses decreased due to lower past due customer receivable balances.

Inventories

The following table summarizes our inventories balances at June 30, 2022 and December 31, 2021:


	June 30,		December 31,
	2022		2021
	(In Thousands)
Inventories
Fuel	$	51,681	$	41,626
Materials and supplies, net	64,768		60,273
Total inventories	$	116,449	$	101,899

ARO

AES Indiana’s ARO relates primarily to environmental issues involving asbestos-containing materials, ash ponds, landfills and miscellaneous contaminants associated with its generating plants, transmission system and distribution system. The following is a roll forward of the ARO legal liability for the six months ended June 30, 2022 and 2021, respectively:


	For the Six Months Ended June 30,
	2022		2021
	(In Thousands)
Balance as of January 1	$	189,509	$	195,236
Liabilities incurred	1,059		—
Liabilities settled	(5,961)		(4,302)
Revisions to cash flow and timing estimates	22,402		—
Accretion expense	3,921		3,992
Balance as of June 30	$	210,930	$	194,926

AES Indiana recorded adjustments to its ARO liabilities of $22.4 million for the six months ended June 30, 2022, primarily to reflect increases to estimated ash pond closure costs. As of June 30, 2022 and December 31, 2021, AES Indiana did not have any assets that are legally restricted for settling its ARO liability. For further information on AES Indiana’s ARO, see Note 3, "Property, Plant and Equipment - ARO" to IPALCO’s 2021 Form 10-K.

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of AOCI / (AOCL) by component during the three months ended June 30, 2022 and 2021 are as follows (in Thousands):


Details about AOCI / (AOCL) components	Affected line item in the Condensed Consolidated Statements of Operations	Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021
Net losses on cash flow hedges (Note 4):	Interest expense	$	1,807	$	1,807	$	3,614	$	1,204
	Income tax effect	(449)		(431)		(898)		(284)
Total reclassifications for the period, net of income taxes		$	1,358	$	1,376	$	2,716	$	920

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

Operating Expenses – Other, Net

Operating expenses – Other, net generally includes gains or losses on asset sales, dispositions or acquisitions, gains or losses on the sale or acquisition of businesses, and other expense or income from miscellaneous operating transactions. For the six months ended June 30, 2022, the $3.2 million is primarily due to a gain on remeasurement of contingent consideration associated with the Hardy Hills Solar Project acquisition.

New Accounting Pronouncements Adopted in 2022

The following table provides a brief description of recent accounting pronouncements that had an impact on the Company's Financial Statements. 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.



ASU Number and Name	Description	Date of Adoption	Effect on the Financial Statements upon adoption
2020-04 and 2021-01, 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 31, 2022).	March 12, 2020 - December 31, 2022	The Company is implementing the reference rate reform and does not expect these amendments to have a material impact on the Financial Statements.

2. REGULATORY MATTERS

2022 IRP

Electric utilities in Indiana are required to submit Integrated Resource Plans (IRPs) every three years. The IRPs are subject to a rigorous stakeholder process. IRPs describe how the utility plans to deliver safe, reliable, and efficient electricity at just and reasonable rates. AES Indiana held public advisory meetings for the 2022 IRP in January, April and June of 2022. Changes to our generation portfolio are evaluated and decided through the IRP. The 2022 IRP is expected to be filed in the fourth quarter of 2022.

AES Indiana issued an all-source Request for Proposal on April 14, 2022, in order to competitively procure replacement capacity; such need is being evaluated in AES Indiana's 2022 IRP.

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 replaced the net metering program beginning in July 2022, when net metering was no longer available to new customers. The IURC approved the EDG rate by order dated January 26, 2022, On March 16, 2022, the IURC denied the petition for reconsideration filed by the other parties on February 15, 2022. The matter remains subject to the pending appeal filed by the other parties on February 22, 2022, which is currently being held in abeyance by the Indiana Court of Appeals pending resolution of a petition to transfer to the Indiana Supreme Court filed in a similar case involving a different and unaffiliated utility. The stay was extended by the Indiana Court of Appeals on July 11, 2022 and remains in effect.

Deferred Fuel

The Eagle Valley CCGT was on unplanned outage from late April 2021 until mid-March 2022, impacting several FAC periods. The FAC 133 IURC Order issued on November 24, 2021 approved the FAC 133 fuel cost factor on an interim basis subject to refund pending the outcome of a sub-docket created to examine the Eagle Valley CCGT extended outage. A procedural schedule for the sub-docket has been established by the IURC. AES Indiana filed testimony in the FAC sub-docket in May 2022 and the evidentiary hearing is scheduled to be held in October 2022.

AES Indiana's subsequent FAC filings have included a reduced FAC factor requested by AES Indiana in order to mitigate the rate impact on customers, primarily caused by rising commodity pricing and the Eagle Valley extended

outage, that deferred the collection of certain variances estimated to be due to the Eagle Valley unplanned outage until a future FAC filing or the resolution in the FAC sub-docket for the Eagle Valley outage. As such, certain FAC deferrals are recorded in long-term regulatory assets as the timing of collection is unknown.

House Bill 1002

The 2022 Indiana General Assembly recently passed House Enrolled Act 1002, which includes language regarding the repeal of the Utility Receipts Tax ("URT"). AES Indiana filed a rate adjustment with the IURC on April 29, 2022, which was approved by the IURC on June 28, 2022. AES Indiana began charging the new rates excluding URT in July 2022.

3. FAIR VALUE

The fair value of current 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. Because 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 2021 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 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 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 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 Condensed Consolidated Statements of Operations.

Forward Power Contracts

AES Indiana entered into forward purchase power contracts during the three and six months ended June 30, 2022 and 2021, respectively. As of June 30, 2022 and December 31, 2021, respectively, all outstanding forward power contracts had settled and there was no notional amount outstanding. 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

IPALCO's 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 AOCI / (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, 2022 and December 31, 2021 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, 2022		Based on quoted market prices in active markets		Other observable inputs		Unobservable inputs
	(In Thousands)
Financial assets:
VEBA investments:
Money market funds	$	8	$	8	$	—	$	—
Mutual funds	3,283		—		3,283		—
Total VEBA investments	3,291		8		3,283		—
FTRs	14,527		—		—		14,527

Total financial assets measured at fair value	$	17,818	$	8	$	3,283	$	14,527
Financial liabilities:
Interest rate hedges	$	3,473	$	—	$	3,473	$	—

Total financial liabilities measured at fair value	$	3,473	$	—	$	3,473	$	—


Assets and Liabilities at Fair Value
			Level 1		Level 2		Level 3
	Fair value at December 31, 2021		Based on quoted market prices in active markets		Other observable inputs		Unobservable inputs
	(In Thousands)
Financial assets:
VEBA investments:
Money market funds	$	11	$	11	$	—	$	—
Mutual funds	3,594		—		3,594		—
Total VEBA investments	3,605		11		3,594		—
FTRs	1,235		—		—		1,235
Total financial assets measured at fair value	$	4,840	$	11	$	3,594	$	1,235
Financial liabilities:
Interest rate hedges	$	49,382	$	—	$	49,382	$	—
Total financial liabilities measured at fair value	$	49,382	$	—	$	49,382	$	—

Financial Instruments not Measured at Fair Value in the Condensed 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, 2022				December 31, 2021
	Face Value		Fair Value		Face Value		Fair Value
	(In Thousands)
Fixed-rate	$	2,683,800	$	2,589,833	$	2,683,800	$	3,169,118
Variable-rate	270,000		270,000		60,000		60,000
Total indebtedness	$	2,953,800	$	2,859,833	$	2,743,800	$	3,229,118

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

•unamortized deferred financing costs of $24.5 million and $25.2 million at June 30, 2022 and December 31, 2021, respectively; and

•unamortized discounts of $6.3 million and $6.4 million at June 30, 2022 and December 31, 2021, respectively.

4. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

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 2021 Form 10-K.

At June 30, 2022, 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	$	—	$	400,000
FTRs	Not Designated	MWh	11,550		—		11,550

(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 AOCI / (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)	2022		2021
Beginning accumulated derivative loss in AOCL	$	(12,484)	$	(13,826)

Net gains / (losses) associated with current period hedging transactions	18,925		(17,143)
Net losses reclassified to interest expense, net of tax	1,358		1,376
Ending accumulated derivative gain / (loss) in AOCI / (AOCL)	$	7,799	$	(29,593)


	Interest Rate Hedges for the Six Months Ended June 30,
$ in thousands (net of tax)	2022		2021
Beginning accumulated derivative loss in AOCL	$	(29,407)	$	(43,420)

Net gains associated with current period hedging transactions	34,490		12,907
Net losses reclassified to interest expense, net of tax	2,716		920
Ending accumulated derivative gain / (loss) in AOCI / (AOCL)	$	7,799	$	(29,593)

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)	27

Derivatives Not Designated as Hedge

AES Indiana's FTRs and 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 using the income approach when acquired and subsequently amortized over the annual period as they are used. The forward power contracts are recorded at fair value using the market approach with changes in the fair value charged or credited to the Consolidated Statements of Operations in the period in which the change occurred. This is commonly referred to as "MTM accounting". Realized gains and losses on the forward power contracts are included in future FAC filings, therefore any realized and unrealized gains and losses are deferred as regulatory liabilities or regulatory assets. There were realized gains of $1.3 million related to forward power contracts for the three and six months ended June 30, 2022. 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. The net gains resulting from these contracts have been deferred and included with deferred fuel costs in "Regulatory assets, non-current" on the accompanying Condensed Consolidated Balance Sheets.

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, 2022 and December 31, 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, 2022		December 31, 2021
FTRs	Not a Cash Flow Hedge	Prepayments and other current assets	$	14,527	$	1,235

Interest rate hedges	Cash Flow Hedge	Derivative liabilities, non-current	$	3,473	$	49,382

5. DEBT

Long-Term Debt

The following table presents our long-term debt:


		June 30,		December 31,
Series	Due	2022		2021
		(In Thousands)
AES Indiana first mortgage bonds:
3.125% (1)	December 2024	$	40,000	$	40,000
0.65% (1)	August 2025	40,000		40,000
0.75% (2)	April 2026	30,000		30,000
0.95% (2)	April 2026	60,000		60,000
1.40% (1)	August 2029	55,000		55,000
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
Unamortized discount – net		(5,776)		(5,855)
Deferred financing costs		(17,411)		(17,913)
Total AES Indiana first mortgage bonds		1,780,613		1,780,032
Total Long-term Debt – AES Indiana		1,780,613		1,780,032
Long-term Debt – IPALCO Enterprises, Inc.:
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		(476)		(527)
Deferred financing costs		(6,655)		(7,319)
Total Long-term Debt – IPALCO Enterprises, Inc.		872,869		872,154
Total Consolidated IPALCO Long-term Debt		2,653,482		2,652,186
Less: Current Portion of Long-term Debt		—		—
Net Consolidated IPALCO Long-term Debt		$	2,653,482	$	2,652,186

(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.

Significant Transactions

AES Indiana Term Loan

In June 2022, AES Indiana entered into an unsecured $200.0 million 364-day Term Loan Agreement. The Term Loan Agreement was fully drawn at closing with the proceeds being used for general corporate purposes. This agreement matures on June 22, 2023, and bears interest at variable rates as described in the Term Loan Agreement. The Term Loan Agreement contains customary representations, warranties and covenants, including a leverage covenant consistent with the leverage covenant contained in AES Indiana's Credit Agreement.

AES Indiana has classified this Term Loan Agreement as short-term indebtedness as it matures June 2023. Management plans to refinance this Term Loan Agreement with new debt. In the event that we are unable to refinance this Term Loan Agreement on acceptable terms, AES Indiana anticipates it will have available borrowing capacity on its revolving credit facility that could be used to satisfy the obligation.

AES Indiana First Mortgage Bonds and Recent Indiana Finance Authority Bond Issuances

In July 2021, the Indiana Finance Authority issued at the request 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 an interest rate of 1.40% due August 1, 2029 and $40 million Series 2021B notes at an interest rate of 0.65% due August 1, 2025 to secure the loan of proceeds from these bonds issued by the Indiana Finance Authority. Proceeds of the bond offering were used to refund $95 million of Indiana Finance Authority Environmental Facilities Refunding Revenue Bonds Series 2011A&B at a redemption price of 100% of par.

IPALCO’s Senior Secured Notes

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, 2022 and December 31, 2021, AES Indiana had $70.0 million and $60.0 million in outstanding borrowings on the committed Credit Agreement, respectively.

6. INCOME TAXES

Effective Tax Rate

IPALCO's provision for income taxes is based on the estimated annual effective tax rate, plus discrete items. The effective combined state and federal income tax rates were 20.2% and 20.9% for the three and six months ended June 30, 2022, respectively, as compared to 20.7% and 20.6% for the three and six months ended June 30, 2021, respectively. The year-to-date rate is different from the combined federal and state statutory rate of 24.9% 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.

IPALCO’s income tax expense for the six months ended June 30, 2022, was calculated using the estimated annual effective income tax rate for 2022 of 20.9% on ordinary income. Management estimates the annual effective tax rate based on its forecast of annual pre-tax income or loss.

AES files federal and state income tax returns which consolidate IPALCO and its subsidiaries. Under a tax sharing agreement with AES, IPALCO is responsible for the income taxes associated with its own taxable income and records the provision for income taxes using a separate return method.

7. BENEFIT PLANS

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,
	2022		2021		2022		2021
	(In Thousands)				(In Thousands)
Components of net periodic benefit (credit) / cost:
Service cost	$	2,239	$	2,335	$	4,476	$	4,669
Interest cost	4,525		3,915		9,040		7,830
Expected return on plan assets	(8,914)		(10,454)		(17,833)		(20,908)
Amortization of prior service cost	648		736		1,295		1,472
Amortization of actuarial loss	605		1,382		1,212		2,764
Net periodic benefit (credit) / cost	$	(897)	$	(2,086)	$	(1,810)	$	(4,173)

The components of net periodic benefit (credit) / cost other than service cost are included in "Other income, net" in the 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 $4.0 million and $3.9 million at June 30, 2022 and December 31, 2021, respectively, were not material to the Financial Statements in the periods covered by this report.

8. COMMITMENTS AND CONTINGENCIES

Guarantees

We and certain of our subsidiaries enter into agreements from time to time providing financial or performance assurance to third parties for certain of our subsidiaries as part of our business, including guarantees and stand-by letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to the subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the subsidiary's intended commercial purposes. At June 30, 2022 and December 31, 2021, AES Indiana had issued $280.8 million and $226.2 million of guarantees, respectively, and no stand-by letters of credit.

Legal Matters

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, 2022 and December 31, 2021, total legal loss contingencies accrued were $0.0 million and $0.2 million, respectively, which primarily related to personal injury litigation. The legal loss contingencies and settlement related accruals are included in "Other Non-Current Liabilities" on the accompanying Condensed Consolidated Balance Sheets. We maintain an amount of insurance protection for such litigation that we believe is adequate. As of June 30, 2022 and December 31, 2021, we have $0.7 million and $12.5 million, respectively, of receivables for insurance recoveries determined to be probable recorded in "Prepayments and other current assets" on the accompanying Condensed Consolidated Balance Sheets. 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 Matters

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, including GHGs, into the environment; climate change; 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 three 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 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 previously had a contingent liability recorded related to these New Source Review and other CAA NOV matters.

Coal Ash Insurance Litigation

In August 2021, AES Indiana filed a civil action against various third-party insurance providers. The complaint seeks damages for breach of contract and a declaratory judgment declaring that such insurers must defend and indemnify AES Indiana under liability insurance policies issued between 1950 and the filing of the civil action against certain environmental liabilities arising from CCR at Harding Street, Petersburg and Eagle Valley. At this time, we cannot predict the outcome of this matter.

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 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, 2022						June 30, 2021
	Utility		All Other		Total		Utility		All Other		Total
Revenues	$	389,614	$	—	$	389,614	$	330,587	$	—	$	330,587
Depreciation and amortization	$	66,266	$	—	$	66,266	$	62,994	$	—	$	62,994
Interest expense	$	21,262	$	10,958	$	32,220	$	21,255	$	10,944	$	32,199
Earnings/(loss) from operations before income tax	$	10,008	$	(11,201)	$	(1,193)	$	32,587	$	(10,872)	$	21,715

	Six Months Ended						Six Months Ended
	June 30, 2022						June 30, 2021
	Utility		All Other		Total		Utility		All Other		Total
Revenues	$	813,725	$	—	$	813,725	$	692,788	$	—	$	692,788
Depreciation and amortization	$	132,286	$	—	$	132,286	$	126,083	$	—	$	126,083
Interest expense	$	42,006	$	21,916	$	63,922	$	42,776	$	19,490	$	62,266
Earnings/(loss) from operations before income tax	$	80,748	$	(22,255)	$	58,493	$	89,882	$	(19,348)	$	70,534

	As of June 30, 2022						As of December 31, 2021
	Utility		All Other		Total		Utility		All Other		Total
Total assets	$	5,465,375	$	15,238	$	5,480,613	$	5,222,987	$	16,780	$	5,239,767

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 2021 Form 10-K for further discussion of our retail, wholesale and miscellaneous revenues.

AES Indiana’s revenue from contracts with customers was $382.6 million and $318.5 million for the three months ended June 30, 2022 and 2021, respectively, and $799.2 million and $672.2 million for the six months ended June 30, 2022 and 2021, respectively. The following tables present our revenue from contracts with customers and other revenue (in thousands):


	For the Three Months Ended June 30,
	2022		2021
Retail Revenues
Retail revenue from contracts with customers:
Residential	$	144,476	$	129,254
Small commercial and industrial	56,944		48,208
Large commercial and industrial	149,741		127,009
Public lighting	2,351		2,270
Other (1)	4,260		4,175
Total retail revenue from contracts with customers	357,772		310,916
Alternative revenue programs	6,470		11,710
Wholesale Revenues
Wholesale revenues from contracts with customers:	21,476		4,918
Miscellaneous Revenues
Transmission and other revenue from contracts with customers	3,333		2,692
Other miscellaneous revenues (2)	563		351
Total Revenues	$	389,614	$	330,587

(1)Other retail revenue from contracts with customers includes miscellaneous charges to customers, including reconnection and late fee charges

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


	For the Six Months Ended June 30,
	2022		2021
Retail Revenues
Retail revenue from contracts with customers:
Residential	$	338,892	$	289,757
Small commercial and industrial	120,592		102,725
Large commercial and industrial	287,946		240,449
Public lighting	4,752		4,456
Other (1)	8,785		8,366
Total retail revenue from contracts with customers	760,967		645,753
Alternative revenue programs	12,924		19,305
Wholesale Revenues
Wholesale revenues from contracts with customers:	33,317		21,027
Miscellaneous Revenues
Transmission and other revenue from contracts with customers	4,948		5,373
Other miscellaneous revenues (2)	1,569		1,330
Total Revenues	$	813,725	$	692,788

(1)Other retail revenue from contracts with customers includes miscellaneous charges to customers, including reconnection and late fee charges

(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 $173.5 million and $163.0 million as of June 30, 2022 and December 31, 2021, respectively. Payment terms for all receivables from contracts with customers typically do not extend beyond 30 days, though as a result of COVID-19, AES Indiana began offering expanded payment arrangements for customers.

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 $0.0 million as of June 30, 2022 and December 31, 2021, respectively. During the three months ended June 30, 2022 and 2021, we recognized revenue of $0.0 million and $0.2 million related to this contract liability balance, respectively. During the six months ended June 30, 2022 and 2021, we recognized revenue of $0.0 million and $0.5 million related to this contract liability balance, respectively.

11. LEASES

Lessee

The following table summarizes the components of lease expense recognized in "Operating Costs and Expenses" on the accompanying Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2022 and 2021, respectively (in thousands):


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
Components of Lease Cost	2022		2021		2022		2021

Finance lease cost:
Amortization of right- of-use assets	$	130	$	—	$	281	$	—
Interest on lease liabilities	188		—		403		—



Total lease cost	$	318	$	—	$	684	$	—

Operating cash outflows from finance leases were $0.3 million for the three and six months ended June 30, 2022.

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 Condensed Consolidated Statements of Operations was $0.3 million and $0.3 million for the three months ended June 30, 2022 and 2021, respectively, and was $0.6 million and $0.6 million for the six months ended June 30, 2022 and 2021, respectively. Underlying gross assets and accumulated depreciation of operating leases included in Total net property, plant and equipment on the Condensed Consolidated Balance Sheets were $4.4 million and $1.0 million, respectively, as of June 30, 2022 and December 31, 2021.

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, 2022.

The following table shows the future minimum lease receipts as of June 30, 2022 for the remainder of 2022 through 2026 and thereafter (in thousands):


	Operating Leases
2022	$	488
2023	906
2024	786
2025	553
2026	554
Thereafter	1,559
Total	$	4,846

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. 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. 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.

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" of Part II of this quarterly report and “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in IPALCO’s 2021 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 2021 Form 10-K.

EXECUTIVE SUMMARY

Compared with the same periods in the prior year, the results for the three and six months ended June 30, 2022 reflect lower earnings from operations before income tax of $22.9 million, or 105.5% and $12.0 million, or 17.1%, respectively, primarily due to factors including, but not limited to:

•decrease due to higher operation and maintenance expenses primarily due to higher outage and plant maintenance costs and storm costs, partially offset by

•increase in volumes of retail kWh sold primarily due to higher weather-normalized demand.

See "Results of Operations" below for further discussion.

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	2022		2021		$ change		% change		2022		2021		$ change		% change

REVENUES	$	389,614	$	330,587	$	59,027	17.9	%	$	813,725	$	692,788	$	120,937	17.5	%

OPERATING COSTS AND EXPENSES:
Fuel	99,918		52,840		47,078		89.1	%	204,060		137,571		66,489		48.3	%
Power purchased	46,620		41,748		4,872		11.7	%	94,505		66,331		28,174		42.5	%
Operation and maintenance	139,543		116,381		23,162		19.9	%	250,556		220,330		30,226		13.7	%
Depreciation and amortization	66,266		62,994		3,272		5.2	%	132,286		126,083		6,203		4.9	%
Taxes other than income taxes	10,557		8,745		1,812		20.7	%	22,316		21,696		620		2.9	%
Other, net	—		—		—		—	%	(3,201)		—		(3,201)		—	%
Total operating costs and expenses	362,904		282,708		80,196		28.4	%	700,522		572,011		128,511		22.5	%

OPERATING INCOME	26,710		47,879		(21,169)		(44.2)	%	113,203		120,777		(7,574)		(6.3)	%

OTHER INCOME / (EXPENSE), NET:
Allowance for equity funds used during construction	1,686		1,331		355		26.7	%	3,374		2,705		669		24.7	%
Interest expense	(32,220)		(32,199)		(21)		0.1	%	(63,922)		(62,266)		(1,656)		2.7	%

Other income, net	2,631		4,704		(2,073)		(44.1)	%	5,838		9,318		(3,480)		(37.3)	%
Total other expense, net	(27,903)		(26,164)		(1,739)		6.6	%	(54,710)		(50,243)		(4,467)		8.9	%

(LOSS) / INCOME FROM OPERATIONS BEFORE INCOME TAX	(1,193)		21,715		(22,908)		(105.5)	%	58,493		70,534		(12,041)		(17.1)	%

Income tax (benefit) / expense	(241)		4,505		(4,746)		(105.3)	%	12,254		14,540		(2,286)		(15.7)	%
NET (LOSS) / INCOME	(952)		17,210		(18,162)		(105.5)	%	46,239		55,994		(9,755)		(17.4)	%

Less: Dividends on preferred stock	804		804		—		—	%	1,607		1,607		—		—	%
NET (LOSS) / INCOME APPLICABLE TO COMMON STOCK	$	(1,756)	$	16,406	$	(18,162)	(110.7)	%	$	44,632	$	54,387	$	(9,755)	(17.9)	%

Revenues

Revenues during the three and six months ended June 30, 2022 increased $59.0 million and $120.9 million, respectively, compared to the same periods in 2021, which resulted from the following changes (dollars in thousands):


	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2022		2021		$ Change		% Change	2022		2021		$ Change		% Change
Revenues:
Retail revenues	$	364,241	$	322,627	$	41,614	12.9%	$	773,891	$	665,059	$	108,832	16.4%
Wholesale revenues	21,476		4,918		16,558		336.7%	33,317		21,027		12,290		58.4%
Miscellaneous revenues	3,897		3,042		855		28.1%	6,517		6,702		(185)		(2.8)%
Total revenues	$	389,614	$	330,587	$	59,027	17.9%	$	813,725	$	692,788	$	120,937	17.5%

Heating degree days:
Actual	496		575		(79)		(13.7)%	3,283		3,279		4		0.1%
30-year average	500		504					3,259		3,253

Cooling degree days:
Actual	413		367		46		12.5%	413		367		46		12.5%
30-year average	346		338					349		341

The following table presents additional data on kWh sold:


	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2022	2021	kWh Change	% Change		2022	2021	kWh Change	% Change
kWh Sales (In Millions):
Residential	1,107	1,080	27	2.5	%	2,707	2,609	98	3.8	%
Small commercial and industrial	430	400	30	7.5	%	917	883	34	3.9	%
Large commercial and industrial	1,525	1,494	31	2.1	%	2,958	2,874	84	2.9	%
Public lighting	4	5	(1)	(20.0)	%	9	11	(2)	(18.2)	%
Sales – retail customers	3,066	2,979	87	2.9	%	6,591	6,377	214	3.4	%
Wholesale	318	172	146	84.9	%	532	819	(287)	(35.0)	%
Total kWh sold	3,384	3,151	233	7.4	%	7,123	7,196	(73)	(1.0)	%

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, 2022 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, 2022 as compared to the same period in the prior year:

During the three months ended June 30, 2022, revenue increased $59.0 million to $389.6 million compared to $330.6 million in the same period of the prior year, and during the six months ended June 30, 2022, revenue increased $120.9 million to $813.7 million compared to $692.8 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, 2022 vs. 2021		Six Months Ended June 30, 2022 vs. 2021
Retail revenues:

	Volume:
	Net increase in the volume of kWh sold primarily due to higher weather-normalized demand, as well as favorable weather in our service territory versus the comparable period	$	9.2	$	21.1
	Price:
	Net increase in the weighted average price of retail kWh sold, primarily due to higher fuel revenues	37.6		93.7

	Other:
	Mostly due to decreases in alternative revenue programs as a result of higher DSM shared savings incentives in the prior period	(5.2)		(6.0)

	Net change in retail revenues	41.6		108.8

Wholesale revenues:

	Volume:
	Net increase/(decrease) 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.	4.1		(7.4)
	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.	12.4		19.7

	Net change in wholesale revenues	16.5		12.3

Miscellaneous revenues		0.9		(0.2)

Net change in revenues		$	59.0	$	120.9

Operating Costs and Expenses

The following table illustrates our changes in Operating costs and expenses during the three and six months ended June 30, 2022, respectively, compared to the same periods in 2021 (in thousands):


	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2022		2021		$ Change		% Change		2022		2021		$ Change		% Change
Operating costs and expenses:
Fuel	$	99,918	$	52,840	$	47,078	89.1	%	$	204,060	$	137,571	$	66,489	48.3	%
Power purchased	46,620		41,748		4,872		11.7	%	94,505		66,331		28,174		42.5	%
Operation and maintenance	139,543		116,381		23,162		19.9	%	250,556		220,330		30,226		13.7	%
Depreciation and amortization	66,266		62,994		3,272		5.2	%	132,286		126,083		6,203		4.9	%
Taxes other than income taxes	10,557		8,745		1,812		20.7	%	22,316		21,696		620		2.9	%
Other, net	—		—		—		—		(3,201)		—		(3,201)		—
Total operating costs and expenses	$	362,904	$	282,708	$	80,196	28.4	%	$	700,522	$	572,011	$	128,511	22.5	%

Fuel

The increases in fuel costs of $47.1 million and $66.5 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to the following changes:


$ in millions		Three Months Ended June 30, 2022 vs. 2021		Six Months Ended June 30, 2022 vs. 2021
Volume:
	Coal	$	(14.2)	$	(17.2)
	Natural gas	25.9		20.8
	Oil	(0.1)		(0.1)
	Net change in volume	11.6		3.5
Price:
	Coal	13.1		30.9
	Natural gas	41.1		51.1
	Oil	0.6		0.8
	Deferred fuel	(19.3)		(19.8)
	Net change in price	35.5		63.0

Net change in fuel expense		$	47.1	$	66.5

The increases in the price of fuel during 2022 are reflective of higher market prices for coal and natural gas. 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.

Power Purchased

The increases in power purchased of $4.9 million and $28.2 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to the following changes:


$ in millions	Three Months Ended June 30, 2022 vs. 2021		Six Months Ended June 30, 2022 vs. 2021
Net change in the volume of power purchased primarily due to AES Indiana's generation units running more/(less) frequently, as well as the timing and duration of outages, during these respective periods	$	(13.5)	$	13.3
Net change in the price of power purchased is primarily due to timing of FAC deferrals and amortization, variances in market prices, and changes in mix of contracted renewable and market power purchases	17.1		11.9
Other, net	1.3		3.0
Net change in power purchased costs	$	4.9	$	28.2

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 Eagle Valley CCGT was on unplanned outage from late April 2021 until mid-March 2022, impacting several FAC periods. The IURC has initiated an ongoing sub-docket in FAC-133 (IURC Cause No. 38703-FAC-133 S1) to examine the impact of the Eagle Valley extended outage. Recovery of increases in the volume of power purchased during 2021 and 2022 is subject to approval by the IURC. For further discussion, please see Note 2, "Regulatory Matters - Deferred Fuel" to the Financial Statements of this Form 10-Q. 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 $23.2 million and $30.2 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to the following changes:


$ in millions	Three Months Ended June 30, 2022 vs. 2021		Six Months Ended June 30, 2022 vs. 2021
Increase in maintenance expenses primarily due to the timing of increased outage costs and plant-related projects	$	13.6	$	16.5
Increase in contracted service expenses primarily due to storm costs	6.6		7.2
Increase in DSM program costs (these program costs are recoverable through customer rates and are offset by an increase in DSM revenues)	1.6		4.7
Other, net	1.4		1.8
Net change in operation and maintenance costs	$	23.2	$	30.2

Depreciation and Amortization

The increases in Depreciation and amortization expense of $3.3 million and $6.2 million during the three and six months ended June 30, 2022, 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 increases in Taxes other than income taxes of $1.8 million and $0.6 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were mostly attributed to higher property taxes as a result of higher assessed values.

Other, Net

The changes in Other, net of $0.0 million and $3.2 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to a gain on remeasurement of contingent consideration associated with the Hardy Hills Solar Project acquisition.

Other Income / (Expense), Net

The following table illustrates our changes in Other income / (expense), net during the three and six months ended June 30, 2022, respectively, compared to the same periods in 2021 (in thousands):


	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2022		2021		$ Change		% Change		2022		2021		$ Change		% Change
Other income/(expense), net
Allowance for equity funds used during construction	$	1,686	$	1,331	$	355	26.7	%	$	3,374	$	2,705	$	669	24.7	%
Interest expense	(32,220)		(32,199)		(21)		0.1	%	(63,922)		(62,266)		(1,656)		2.7	%

Other income, net	2,631		4,704		(2,073)		(44.1)	%	5,838		9,318		(3,480)		(37.3)	%
Total other income/(expense), net	$	(27,903)	$	(26,164)	$	(1,739)	6.6	%	$	(54,710)	$	(50,243)	$	(4,467)	8.9	%

Interest Expense

The increases in Interest expense of $0.0 million and $1.7 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to higher amortization of unrealized losses on interest rate hedges.

Other Income, Net

The decreases in Other income, net of $2.1 million and $3.5 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to decreases in defined benefit plan income of $1.4 million and $2.7 million, respectively, mostly as a result of a lower expected return on plan assets compared to the prior year.

Income Tax (Benefit) / Expense

The following table illustrates our changes in Income tax expense during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year (in thousands):


	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2022		2021		$ Change		% Change		2022		2021		$ Change		% Change
Income tax (benefit) / expense	$	(241)	$	4,505	$	(4,746)	(105.3)	%	$	12,254	$	14,540	$	(2,286)	(15.7)	%

The decreases in Income tax (benefit) / expense of $4.7 million and $2.3 million during the three and six months ended June 30, 2022, respectively, compared to the same periods of the prior year were primarily due to lower pre-tax income versus the comparable period.

KEY TRENDS AND UNCERTAINTIES

During the remainder of 2022 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 2021 Form 10-K and "Item 1A. Risk Factors" of this Form 10-Q.

Operational

COVID-19 Pandemic

The COVID-19 pandemic has impacted global economic activity, including electricity and energy consumption, and caused significant volatility in financial markets. Throughout the COVID-19 pandemic we have conducted our essential operations without significant disruption. 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.

The COVID-19 pandemic primarily impacted our retail sales demand. Retail sales demand decreased in 2020 mostly from commercial and industrial customers but has recovered. While we have continued to experience some COVID-19 impacts into 2022, such impacts have not been material nor do we expect they will be material, particularly if reduced social distancing measures and improvements in energy demand continue. The magnitude and duration of the COVID-19 pandemic is unknown at this time, however, and could have material and adverse effects on our results of operations, financial condition and cash flows in future periods. Also see "Item 1A. Risk Factors" of our 2021 Form 10-K.

We have not had nor do we expect to have a significant impact to our access to capital or our liquidity position as a result of the COVID-19 pandemic. We also have not experienced any material credit-related impacts due to the COVID-19 pandemic, but continue to monitor and manage our credit exposures in a prudent manner.

Trade Restrictions and Supply Chain

On March 29, 2022, the U.S. Department of Commerce (“Commerce”) announced the initiation of an investigation into whether imports into the U.S. of solar cells and panels imported from Cambodia, Malaysia, Thailand and Vietnam are circumventing antidumping and countervailing duty orders on solar cells and panels from China. This investigation resulted in disruptions to the import of solar panels from Southeast Asia. On July 6, 2022, President Biden issued a Proclamation waiving any tariffs that result from this investigation for a 24-month period. Following President Biden’s proclamation, suppliers in Southeast Asia have begun importing panels again to the U.S. Additionally, certain suppliers could be blocked from importing solar cells and panels to the U.S. under the Uyghur Forced Labor Prevention Act (UFLPA). The UFLPA seeks to block the import of products made with forced labor in certain areas of China. We are monitoring the impacts of these matters on AES Indiana's solar projects.

While we have executed agreements for AES Indiana's solar projects, further disruptions may impact our suppliers’ ability or willingness to meet their contractual agreements with respect to these projects on terms that we deem satisfactory. The impact of any adverse Commerce determination, the impact of the UFLPA, future disruptions to the solar panel supply chain and their effect on AES Indiana's solar project development and construction activities is uncertain. AES Indiana will continue to monitor developments and take prudent steps towards managing our renewables projects.

Capital Projects

Our construction projects have experienced some indications of delays and price increases; however, they are currently 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.

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 - Macroeconomic and Political - Reference Rate Reform" of IPALCO's 2021 Form 10-K, in July 2017, the UK Financial Conduct Authority announced that it intended 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 has determined that it will cease publication of the one-month, three-month, six-month, and 12-month USD LIBOR rates by June 30, 2023. We hold debt and derivative contracts that use LIBOR as an interest rate benchmark. In order to facilitate an organized transition from LIBOR to alternative benchmark rate(s), we have established a process to measure and mitigate risks associated with the cessation of LIBOR. As part of this initiative, alternative benchmark rates have been, and continue to be, assessed, and implemented for newly executed agreements. Many of our existing agreements include provisions designed to facilitate an orderly transition from LIBOR,and interest rate derivatives address the LIBOR transition through the adoption of the ISDA 2020 IBOR Fallbacks Protocol and subsequent amendments. To the extent that the terms of the credit agreements and derivative instruments do not align following the cessation of LIBOR rates, we will seek to negotiate contract amendments with counterparties or additional derivatives contracts.

U.S. Income Tax

The macroeconomic and political environments in the U.S. have changed during 2021 and 2022 This could result in significant impacts to tax law. For example, in the first quarter of 2022, the Biden Administration released its fiscal year 2023 budget, which includes proposed U.S. Corporate tax reform proposals that would increase the U.S. corporate income tax rate. Additional details regarding these potential changes in law are expected to be made available later this year.

Inflation

In the markets in which we operate, there have been higher rates of inflation in recent months. If inflation continues to increase in our markets, it may increase our expenses that we may not be able to pass through to customers. It may also increase the costs of some of our construction projects. AES Indiana may have the ability to recover operations and maintenance costs through the regulatory process, however, timing impacts on recovery may vary. In addition, the cost of fuel, specifically coal and natural gas, has risen and may remain at current levels or continue to rise further into 2022. Our exposure to fluctuations in the price of fuel is limited because of our FAC. If we are unable to timely or fully recover our fuel and purchased power costs, however, it could have a material adverse effect on our results of operations, financial condition and cash flows.

Regulatory

Please see Note 2, "Regulatory Matters" to the Financial Statements of this Form 10-Q and Note 2, “Regulatory Matters” to IPALCO’s 2021 Form 10-K for a discussion of regulatory matters. In addition, the following discussion of the impact of regulatory matters on the Company updates the discussion provided in “Item 1. Business - Regulatory Matters” in IPALCO’s 2021 Form 10-K.

2022 IRP

In January 2022, AES Indiana held its first public advisory meeting for the 2022 IRP. In February 2022, AES announced its intent to exit coal generation by year-end 2025 versus prior expectation of a reduction to below 10% by year-end 2025, subject to necessary approvals. Changes to AES Indiana's generation portfolio are evaluated and decided through the IRP. AES Indiana issued an all-source Request for Proposal on April 14, 2022, in order to

competitively procure replacement capacity; such need is being evaluated in AES Indiana's 2022 IRP. For further discussion, see Note 2, "Regulatory Matters - 2022 IRP" to the Financial Statements of this Form 10-Q and Note 2, "Regulatory Matters - IRP Filing and Replacement Generation" in IPALCO’s 2021 Form 10-K.

Environmental

We are subject to numerous environmental and climate change laws and regulations in the jurisdictions in which we operate. We face certain risks and uncertainties related to these environmental and climate change 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 addition, the following discussion of the impact of environmental laws and regulations on the Company updates the discussion provided in “Item 1. Business - Environmental Matters” in IPALCO’s 2021 Form 10-K.

CSAPR and 2015 Ozone NAAQS FIP

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 and affected facilities receive fewer ozone season NOx allowances beginning in 2017. Following legal challenges related to the CSAPR Update Rule, on April 30, 2021, EPA issued the Revised CSAPR Update Rule. The Revised CSAPR Update Rule required affected EGUs within certain states (including Indiana) to participate in a new trading program, the CSAPR NOx Ozone Season Group 3 trading program. These affected EGUs received fewer ozone season NOx Ozone Season allowances beginning in 2021, which may result in the need to purchase additional allowances.

On April 6, 2022, the EPA published a proposed Federal Implementation Plan ("FIP") to address air quality impacts with respect to the 2015 Ozone NAAQS. The rule would establish a revised CSAPR NOx Ozone Season Group 3 trading program for 25 states, including Indiana. In addition to other requirements, if finalized, EGUs in these states would begin receiving fewer allowances as soon as 2023, which may result 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.

CWA – Facility Response Plan

On March 28, 2022, EPA published a proposed rule to establish Facility Response Plan (“FRP”) requirements for non-transportation onshore facilities that store CWA hazardous substances and meet certain criteria and thresholds. It is too early to determine whether this proposed rule may have a material impact on our business, financial condition or results of operation.

Waste Management and CCR

In the course of operations, our facilities generate solid and liquid waste materials requiring eventual disposal or processing. Waste materials generated at our electric power and distribution facilities include asbestos, CCR, oil, scrap metal, rubbish, small quantities of industrial hazardous wastes such as spent solvents, tree-and-land-clearing wastes and polychlorinated biphenyl contaminated liquids and solids. We endeavor to ensure that all our solid and

liquid wastes are disposed of in accordance with applicable national, regional, state and local regulations. With the exception of CCR, we do not usually physically dispose of waste materials on our property. Instead, they are usually shipped off-site for final disposal, treatment or recycling. Some of our CCRs are beneficially used on-site and offsite, including as a raw material for production of wallboard, and concrete or cement, and some are disposed off-site in permitted disposal facilities. A small amount of CCR, which consists of bottom ash, fly ash and air pollution control wastes, is disposed of at our Petersburg coal-fired power generation plant using an engineered, permitted landfill.

The EPA's final CCR rule became effective in October 2015 (the "CCR Rule"). Generally, the rule regulates CCR as nonhazardous solid waste and establishes national minimum criteria for existing and new CCR landfills and existing and new CCR ash ponds, including location restrictions, design and operating criteria, groundwater monitoring, corrective action and closure requirements and post-closure care. The 2016 Water Infrastructure Improvements for the Nation Act ("WIIN Act") includes provisions to implement the CCR rule through a state permitting program, or if the state chooses not to participate, a federal permit program. On February 20, 2020, the EPA published a proposed rule to establish a federal CCR permit program that would operate in states without approved CCR permit programs. If this rule is finalized before Indiana establishes a final state-level CCR permit program, AES Indiana could eventually be required to apply for a federal CCR permit from the EPA. On October 13, 2021, IDEM issued a First Notice of Comment Period regarding establishment of a state-level CCR permit program. The EPA has indicated that they will implement a phased approach to amending the CCR Rule, which is ongoing. The CCR Rule, current or proposed amendments to the CCR Rule, the results of groundwater monitoring data or the outcome of CCR-related litigation could have a material impact on our business, financial condition and results of operations. We would seek recovery of any resulting expenditures; however, there is no guarantee we would be successful in this regard. See Note 3, “Property, Plant and Equipment - ARO” in IPALCO’s 2021 Form 10-K and Note 8, “Commitments and Contingencies - Coal Ash Insurance Litigation” to the Financial Statements of this Form 10-Q for further discussion.

On August 28, 2020, the EPA published the CCR Part A Rule that, among other amendments, required certain CCR units to cease waste receipt and initiate closure by April 11, 2021. The CCR Part A Rule also allowed for extensions of the April 11, 2021 deadline if EPA determines certain criteria are met. Facilities seeking such an extension were required to submit a demonstration to EPA by November 30, 2020. On January 11, 2022, EPA released prepublication versions of proposed determinations regarding nine CCR Part A Rule demonstrations. On the same day, EPA issued four compliance-related letters notifying certain other facilities of their compliance obligations under the federal CCR regulations. On April 8, 2022, petitions for review were filed challenging these EPA actions. The petitions are consolidated in Electric Energy, Inc. v. EPA. On July 12, 2022, EPA released prepublication determinations regarding two CCR Part A Rule demonstrations. While AES Indiana did not receive a proposed determination nor a letter, the determinations and letters include interpretations regarding implementation of the CCR Rule. It is too early to determine the impact of these letters or any determinations that may be made.

Emission Guidelines for Greenhouse Gas Emissions from Existing Electric Utility Generating Units

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, which among other things, had called on states to mandate that power companies shift electricity generation to lower or zero carbon fuel sources. 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 did 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. On October 29, 2021, the U.S. Supreme Court granted petitions to review the decision by the D.C. Circuit to vacate the ACE Rule. On June 30, 2022, Supreme Court reversed the judgment of the D.C. Circuit Court and remanded for further proceedings consistent with its opinion. The opinion held that the “generation shifting” approach in the CPP exceeded the authority granted to EPA by Congress under Section 111(d) of the CAA. The impact of the results of

further proceedings and potential future greenhouse gas emissions regulations remains uncertain, but it could be material.

Due to the uncertainty of these regulations, and existing and potential associated litigation, it is too early to determine the potential impact, but any rule could have a material impact on our business, financial condition and results of operations. We would seek recovery of any resulting capital expenditures; however, there is no guarantee we would be successful in this regard.

CAPITAL RESOURCES AND LIQUIDITY

Overview

As of June 30, 2022, we had unrestricted cash and cash equivalents of $16.8 million and available borrowing capacity of $180 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. AES Indiana has approval from the FERC to borrow up to $750 million of short-term indebtedness outstanding at any time through July 26, 2024. In November 2021, AES Indiana received an order from the IURC granting authority through December 31, 2024 to, among other things, issue up to $740 million in aggregate principal amount of long-term debt, all of which authority remains available under the order as of June 30, 2022. This order also grants authority to have up to $750 million of long-term credit agreements and liquidity facilities outstanding at any one time, of which $300 million remains available under the order as of June 30, 2022. As an alternative to the sale of all or a portion of $65 million in principal of the long-term debt, AES Indiana has authority to issue up to $65 million of new preferred stock, all of which authority remains available under the order as of June 30, 2022. 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.

Cash Flows

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


	Six Months Ended June 30,
	2022		2021		$ Change
Net cash provided by operating activities	$	130,469	$	179,099	$	(48,630)
Net cash used in investing activities	(258,727)		(145,491)		(113,236)
Net cash provided by (used in) financing activities	138,172		(39,596)		177,768
Net change in cash and cash equivalents	9,914		(5,988)		15,902
Cash, cash equivalents and restricted cash at beginning of period	6,917		26,622		(19,705)
Cash, cash equivalents and restricted cash at end of period	$	16,831	$	20,634	$	(3,803)

Operating Activities

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


	Six Months Ended June 30,
	2022		2021		$ Change
Net income	$	46,239	$	55,994	$	(9,755)
Depreciation and amortization	132,286		126,083		6,203
Deferred income taxes and investment tax credit adjustments - net	(6,799)		5,866		(12,665)
Other adjustments to net income	(1,383)		(728)		(655)
Net income, adjusted for non-cash items	170,343		187,215		(16,872)
Net change in operating assets and liabilities(1)	(39,874)		(8,116)		(31,758)
Net cash provided by operating activities	$	130,469	$	179,099	$	(48,630)

(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, 2022 compared to the six months ended June 30, 2021 was driven by changes in the following (in thousands):


Decrease from inventory due to increases in purchases in coal inventory and higher coal prices in the current year	$	(30,992)
Decrease from short-term and long-term regulatory assets and liabilities primarily due to larger FAC deferrals	(22,492)
Decrease from accounts receivable primarily due to timing of collections	(12,903)

Increase from accounts payable due to timing of invoices and payments	26,312
Other	8,317
Net change in operating assets and liabilities	$	(31,758)

Investing Activities

Net cash used in investing activities increased $113.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, which was primarily driven by (in thousands):


Higher cash outflows for capital expenditures due to higher growth related capital expenditures primarily from TDSIC Plan and renewable project investments and higher maintenance related capital expenditures	$	(96,535)
Higher cash outflows on cost of removal and regulatory recoverable ARO payments due to timing of such payments	(16,349)
Other	(352)
Net change in investing activities	$	(113,236)

Financing Activities

Net cash provided by financing activities increased $177.8 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, which was primarily driven by (in thousands):


Increase due to proceeds from issuance of Term Loan in 2022	$	200,000
Decrease from net borrowings under revolving credit facilities due to lower net draws on AES Indiana's line of credit in 2022	(15,000)
Other	(7,232)
Net change in financing activities	$	177,768

Liquidity

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.

Indebtedness

For further discussion of our significant debt transactions, please see Note 7, "Debt" to IPALCO’s 2021 Form 10-K and Note 5, "Debt" to the Financial Statements of this Form 10-Q.

Line of Credit

We had the following amounts available under the revolving Credit Agreement:

$ in millions

Type

Maturity

Commitment

Amounts available at June 30, 2022

AES Indiana

Revolving

June 2024

250.0

180.0

Capital Requirements

Capital Expenditures

Our capital expenditure program, including development and permitting costs, for the three-year period from 2022 through 2024 (including amounts already expended in the first six months of 2022) is currently estimated to cost approximately $1.8 billion (excluding environmental compliance), and includes estimates as follows (amounts in millions):


							For the three-year period
	2022		2023		2024		from 2022 through 2024
Transmission and distribution related additions, improvements and extensions	$	157	$	112	$	117	$	386	(1)
TDSIC Plan investments	176		188		165		529		(2)
Power generation related projects	493		249		94		836		(3)
Other miscellaneous equipment	45		27		20		92
Total estimated costs of capital expenditure program	$	871	$	576	$	396	$	1,843

(1) Additions, improvements and extensions to AES Indiana's transmission and distribution lines, substations, power factor and voltage regulating equipment, distribution transformers and street lighting facilities
(2) Includes 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 2026. Total TDSIC costs expended from project inception through June 30, 2022 were $397.0 million.
(3) Includes spending for AES Indiana's power generation and renewable energy projects, excluding any future tax equity contributions

Additionally, estimated capital expenditure spending on environmental compliance costs for the three-year period from 2022 through 2024 includes plans to spend approximately $7.2 million for studies related to cooling water intake requirements in section 316(b) of the CWA. Please see “Item 1. Business - Environmental Matters - Cooling Water Intake Regulations" in IPALCO’s 2021 Form 10-K for additional details.

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

Positive

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

(b) Ratings relate to AES Indiana's 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 2022 and 2021, IPALCO paid $69.9 million and $62.6 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 2021 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 2021 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 three months ended June 30, 2022.

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 2021 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, 2022, 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 2, "Regulatory Matters" and Note 8, “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, 2021 and Form 10-Q for the quarter ended March 31, 2022 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 Forms 10-K and 10-Q, and should be read in conjunction with such Forms 10-K and 10-Q.

ITEM 1A. RISK FACTORS

A listing of the risk factors that we consider to be the most significant to a decision to invest in our securities is provided in our Form 10-K for the fiscal year ended December 31, 2021. Except as described below, there has been no material change in our risk factors as previously disclosed in our 2021 Form 10-K. If any of the events described in our risk factors occur, it could have a material adverse effect on our results of operations, financial condition and cash flows.

The risks and uncertainties described in our risk factors are not the only ones we face. In addition, new risks may emerge at any time, and we cannot predict those risks or estimate the extent to which they may affect our business or financial performance. Our risk factors should be read in conjunction with the other detailed information concerning the Company set forth in the Notes to the Company’s Financial Statements found in Part I, Item 1, and the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” sections included in our filings.

As part of the filing of this Quarterly Report on Form 10-Q, we are further revising, clarifying and supplementing a risk factor from our 2021 Form 10-K. The risk factor below amends and supersedes the risk factor that we filed in connection with our 2021 Form 10-K and should be considered together with the other risk factors described in the 2021 Form 10-K.

Potential security breaches (including cyber-security breaches) and terrorism risks could materially and adversely affect our businesses.

We operate in a highly regulated industry that requires the continued operation of sophisticated systems and network infrastructure at our generation stations, fuel storage facilities and transmission and distribution facilities. We also use various financial, accounting and other systems in our businesses. These systems and facilities are vulnerable to unauthorized access due to hacking, viruses, other cyber-security attacks and other causes. In particular, given the importance of energy and the electric grid, there is the possibility that our systems and facilities could be targets of terrorism or acts of war, and there has been an increased focus on the US energy grid that is believed to be related to the Russia/Ukraine conflict. We have implemented measures to help prevent unauthorized access to our systems and facilities, including network and system monitoring, identification and deployment of secure technologies, and certain other measures to comply with mandatory regulatory reliability standards. Pursuant to NERC requirements, we have a robust cyber-security plan in place and are subject to regular audits by

an independent auditor approved by NERC. We routinely test our systems and facilities against these regulatory requirements in order to measure compliance, assess potential security risks, and identify areas for improvement. In addition, we provide cyber-security training for our employees and perform exercises designed to raise employee awareness of cyber risks on a regular basis. To date, cyber-attacks on our business and operations have not had a material impact on our operations or financial results. Despite our efforts, if our systems or facilities were to be breached or disabled, we may be unable to recover them in a timely manner to fulfill critical business functions, including the supply of electric services to our customers, and we could experience decreases in revenues and increases in costs that could materially and adversely affect our results of operations, cash flows and financial condition.

In the course of our business, we also store and use customer, employee, and other personal information and other confidential and sensitive information, including personally identifiable information and personal financial information. If our or our third-party vendors’ systems were to be breached or disabled, sensitive and confidential information and other data could be compromised, which could result in negative publicity, remediation costs and potential litigation, damages, consent orders, injunctions, fines and other relief.

To help mitigate these risks, we maintain insurance coverage against some, but not all, potential losses, including coverage for illegal acts against us. However, insurance may not be adequate to protect us against all costs and liabilities associated with these risks.

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

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS


Exhibit No.			Document

10.1			$200,000,000 Term Loan Agreement by and among Indianapolis Power & Light Company, d/b/a AES Indiana the Lenders Party Hereto, PNC Bank, National Association, as Administrative Agent, PNC Capital Markets LLC, as Bookrunner and Joint Lead Arranger and U.S. Bank National Association, as Syndication Agent and Joint Lead Arranger Dated as of June 23, 2022
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
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)

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, 2022

/s/ Ahmed Pasha

Ahmed Pasha

Vice President and Chief Financial Officer

(Principal Financial Officer)

Date:

August 4, 2022

/s/ Jon S. Byers

Jon S. Byers

Controller

(Principal Accounting Officer)