10-Q

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 September 30, 2023

or

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

Commission File Number 1-8644

IPALCO ENTERPRISES, INC.

(Exact name of registrant as specified in its charter)

Indiana	35-1575582
(State or other jurisdiction of incorporation or organization)	(I.R.S Employer Identification No.)
One Monument Circle
Indianapolis, Indiana	46204
(Address of principal executive offices)	(Zip code)
Registrant's telephone number, including area code:	(317)-261-8261

    

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 November 2, 2023, 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 L.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 September 30, 2023

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	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	16
	Note 3 - Fair Value	17
	Note 4 - Derivative Instruments and Hedging Activities	19
	Note 5 - Debt	21
	Note 6 - Income Taxes	22
	Note 7 - Benefit Plans	22
	Note 8 - Commitments and Contingencies	23
	Note 9 - Business Segments	24
	Note 10 - Revenues	25
	Note 11 - Leases	26
2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27
	Executive Summary	27
	Results of Operations	28
	Key Trends and Uncertainties	35
	Capital Resources and Liquidity	43
	Critical Accounting Policies and Estimates	46
3.	Quantitative and Qualitative Disclosure About Market Risk	46
4.	Controls and Procedures	46
	PART II - OTHER INFORMATION
1.	Legal Proceedings	47
1A.	Risk Factors	47
2.	Unregistered Sales of Equity Securities and Use of Proceeds	47
3.	Defaults Upon Senior Securities	47
4.	Mine Safety Disclosures	47
5.	Other Information	47
6.	Exhibits	48
	SIGNATURES	49

3

GLOSSARY OF TERMS
The following is a list of frequently used terms, abbreviations or acronyms that are found in this Form 10-Q:
2022 Form 10-K	IPALCO’s Annual Report on Form 10-K for the year ended December 31, 2022, 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.
AFUDC	Allowance for Funds Used During Construction
AOCI	Accumulated Other Comprehensive Income
AOCL	Accumulated Other Comprehensive Loss
ARO	Asset Retirement Obligation
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
BESS	Battery Energy Storage System
BIL	Bipartisan Infrastructure Law, also known as the Infrastructure Investment and Jobs Act
CAA	U.S. Clean Air Act
CCGT	Combined Cycle Gas Turbine
CCR	Coal Combustion Residuals
CDPQ	CDP Infrastructures Fund L.P., a wholly-owned subsidiary of La Caisse de dépôt et placement du Québec
CO2	Carbon Dioxide
CPCN	Certificate of Public Convenience and Necessity
Credit Agreement	$350 million AES Indiana Revolving Credit Facilities Second Amended and Restated Credit Agreement, dated as of December 22, 2022
CSAPR	Cross-State Air Pollution Rule
CWA	U.S. Clean Water Act
DSM	Demand Side Management
EGUs	Electrical Generating Units
ELG	Effluent Limitation Guidelines
EPA	U.S. Environmental Protection Agency
EV	Electric Vehicle
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
FTRs	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles in the United States
GHG	Greenhouse Gas
HLBV	Hypothetical Liquidation Book Value
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
IRA	Inflation Reduction Act of 2022
IRP	Integrated Resource Plan
ITC	Investment Tax Credit

4

IURC	Indiana Utility Regulatory Commission
kWh	Kilowatt hours
MATS	Mercury and Air Toxics Standards
MISO	Midcontinent Independent System Operator, Inc.
MW	Megawatts
MWh	Megawatt hours
NAAQS	National Ambient Air Quality Standards
NOx	Nitrogen Oxide
NPDES	National Pollutant Discharge Elimination System
NSPS	New Source Performance Standards
Pension Plans	Employees’ Retirement Plan of AES Indiana and Supplemental Retirement Plan of AES Indiana
PTC	Production Tax Credit
RFP	Request for Proposal
SEC	United States Securities and Exchange Commission
Service Company	AES US Services, LLC
SO2	Sulfur Dioxide
TDSIC	Transmission, Distribution, and Storage System Improvement Charge
URT	Utility Receipts Tax
U.S.	United States of America
USD	United States Dollars
VEBA	Voluntary Employees' Beneficiary Association
WOTUS	Waters of the U.S.

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.aesindiana.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;

5

•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;

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

•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 2022 Annual Report on Form 10-K and the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section in IPALCO’s 2022 Annual Report on Form 10-K and in our Quarterly Reports on Form 10-Q for the quarters ended March 31, and June 30, 2023 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.

6

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS 

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Operations
(Unaudited)
	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(In Thousands)
REVENUES	$	402,887	$	494,194	$	1,290,580	$	1,307,919
OPERATING COSTS AND EXPENSES:
Fuel	96,698		188,437		411,864		392,497
Power purchased	35,748		57,386		122,410		151,891
Operation and maintenance	120,858		116,969		356,386		367,525
Depreciation and amortization	72,021		66,810		212,292		199,096
Taxes other than income taxes	6,359		5,348		19,779		27,664
Other, net	—		—		—		(3,201)
Total operating costs and expenses	331,684		434,950		1,122,731		1,135,472
OPERATING INCOME	71,203		59,244		167,849		172,447
OTHER (EXPENSE) / INCOME, NET:
Allowance for equity funds used during construction	3,134		1,408		7,089		4,782
Interest expense	(34,471)		(32,630)		(104,510)		(96,552)
Other (expense) / income, net	(633)		2,836		787		8,674
Total other expense, net	(31,970)		(28,386)		(96,634)		(83,096)
INCOME BEFORE INCOME TAX	39,233		30,858		71,215		89,351
Less: income tax expense	3,802		6,020		8,663		18,274
NET INCOME	35,431		24,838		62,552		71,077
Less: dividends on preferred stock	—		803		—		2,410
NET INCOME APPLICABLE TO COMMON STOCK	$	35,431	$	24,035	$	62,552	$	68,667
See Notes to Condensed Consolidated Financial Statements.

7

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)
	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(In Thousands)
Net income	$	35,431	$	24,838	$	62,552	$	71,077
Derivative activity:
Change in derivative fair value, net of income tax effect of $(2,477), $(4,349), $(2,425) and $(15,767), for each respective period	7,482		13,136		7,325		47,627
Reclassification to earnings, net of income tax effect of $(449), $(449), $(1,348) and $(1,348), for each respective period	1,358		1,358		4,073		4,073
Net change in fair value of derivatives	8,840		14,494		11,398		51,700
Other comprehensive income	8,840		14,494		11,398		51,700
Less: dividends on preferred stock	—		803		—		2,410
Comprehensive income	$	44,271	$	38,529	$	73,950	$	120,367

See Notes to Condensed Consolidated Financial Statements.

8

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Balance Sheets
(Unaudited)
	September 30,		December 31,
	2023		2022
	(In Thousands)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	21,537	$	201,548
Accounts receivable, net of allowance for credit losses of $1,064 and $1,117, respectively	184,323		216,523
Inventories	146,396		123,608
Regulatory assets, current	70,578		119,723
Taxes receivable	42,072		18,000
Derivative assets, current	24,273		7,545
Prepayments and other current assets	29,610		19,882
Total current assets	518,789		706,829
NON-CURRENT ASSETS:
Property, plant and equipment	6,722,783		6,982,314
Less: Accumulated depreciation	2,891,090		3,243,968
	3,831,693		3,738,346
Construction work in progress	450,059		294,985
Total net property, plant and equipment	4,281,752		4,033,331
OTHER NON-CURRENT ASSETS:
Intangible assets - net	220,471		138,978
Regulatory assets, non-current	567,525		593,939
Pension plan assets	32,161		33,611
Derivative assets, non-current	—		12,172
Other non-current assets	112,591		70,354
Total other non-current assets	932,748		849,054
TOTAL ASSETS	$	5,733,289	$	5,589,214
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES:
Short-term debt and current portion of long-term debt (see Note 5)	$	479,273	$	—
Accounts payable	206,295		189,845
Accrued taxes	26,443		22,474
Accrued interest	44,772		33,447
Customer deposits	36,732		35,097
Regulatory liabilities, current	53,073		23,348
Accrued and other current liabilities	19,471		19,014
Total current liabilities	866,059		323,225
NON-CURRENT LIABILITIES:
Long-term debt (see Note 5)	2,616,217		3,016,810
Deferred income tax liabilities	359,588		312,641
Regulatory liabilities, non-current	568,646		612,585
Accrued other postretirement benefits	3,027		3,085
Asset retirement obligations	216,791		218,729
Other non-current liabilities	5,366		11,621
Total non-current liabilities	3,769,635		4,175,471
Total liabilities	4,635,694		4,498,696
COMMITMENTS AND CONTINGENCIES (see Note 8)
SHAREHOLDERS' EQUITY:
Paid in capital	1,021,968		1,068,357
Accumulated other comprehensive income	33,667		22,269
Retained earnings / (Accumulated deficit)	41,960		(108)
Total shareholders' equity	1,097,595		1,090,518
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$	5,733,289	$	5,589,214
See Notes to Condensed Consolidated Financial Statements.

9

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(Unaudited)
	Nine Months Ended
	September 30,
	2023		2022
	(In Thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	62,552	$	71,077
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	212,292		199,096
Amortization of deferred financing costs and debt discounts	2,889		2,898
Deferred income taxes and investment tax credit adjustments - net	32,735		(11,137)
Allowance for equity funds used during construction	(7,089)		(4,782)
Change in certain assets and liabilities:
Accounts receivable	32,200		(27,892)
Inventories	(30,264)		(35,826)
Prepayments and other current assets	(9,728)		2,755
Accounts payable	(28,669)		25,619
Accrued and other current liabilities	2,137		4,631
Accrued taxes payable/receivable	(20,103)		1,291
Accrued interest	11,325		12,588
Pension and other postretirement benefit assets and liabilities	1,390		(6,404)
Current and non-current regulatory assets and liabilities	100,822		8,299
Other non-current liabilities	(9,226)		(11,934)
Other - net	(6,176)		(3,743)
Net cash provided by operating activities	347,087		226,536
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(453,671)		(368,636)
Project development costs	(4,589)		(1,435)
Cost of removal payments, net of salvage	(36,749)		(23,075)
Insurance proceeds	4,900		—
Purchase of intangible assets	(44,650)		—
Other	—		(552)
Net cash used in investing activities	(534,759)		(393,698)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under revolving credit facilities	75,000		300,000
Repayments under revolving credit facilities	—		(225,000)
Short-term borrowings	—		200,000
Distributions to shareholders	(66,941)		(101,986)
Preferred dividends of subsidiary	—		(2,410)
Deferred financing costs paid	(85)		(258)
Other	(313)		(34)
Net cash provided by financing activities	7,661		170,312
Net change in cash, cash equivalents and restricted cash	(180,011)		3,150
Cash, cash equivalents and restricted cash at beginning of period	201,553		6,917
Cash, cash equivalents and restricted cash at end of period	$	21,542	$	10,067
Supplemental disclosures of cash flow information:
Cash paid during the period for:
Interest (net of amount capitalized)	$	82,541	$	75,783
Income taxes	$	—	$	31,000
Non-cash investing activities:
Accruals for capital expenditures	$	106,674	$	53,540
Changes to right-of-use assets - finance leases	$	983	$	(3,402)
Non-cash financing activities:
Changes to financing lease liabilities	$	(1,408)	$	(3,402)
See Notes to Condensed Consolidated Financial Statements.

10

IPALCO ENTERPRISES, INC. and SUBSIDIARIES
Condensed Consolidated Statements of Common Shareholders' Equity
and Cumulative Preferred Stock of Subsidiary
For the Three and Nine Months Ended September 30, 2023 and 2022
(Unaudited)
	Paid in Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings /(Accumulated Deficit)		Total Common Shareholders' Equity		Cumulative Preferred Stock of Subsidiary(1)
	(In Thousands)
2023
Beginning Balance	$	1,068,357	$	22,269	$	(108)	$	1,090,518	$	—
Net income	—		—		19,115		19,115		—
Other comprehensive loss	—		(7,174)		—		(7,174)		—
Distributions to shareholders(2)	(12,280)		—		(19,115)		(31,395)		—
Other	31		—		—		31		—
Balance at March 31, 2023	$	1,056,108	$	15,095	$	(108)	$	1,071,095	$	—
Net income	—		—		8,006		8,006		—
Other comprehensive income	—		9,732		—		9,732		—
Distributions to shareholders(2)	(34,177)		—		(1,369)		(35,546)		—
Other	16		—		—		16		—
Balance at June 30, 2023	$	1,021,947	$	24,827	$	6,529	$	1,053,303	$	—
Net income	—		—		35,431		35,431		—
Other comprehensive income	—		8,840		—		8,840		—
Other	21		—		—		21		—
Balance at September 30, 2023	$	1,021,968	$	33,667	$	41,960	$	1,097,595	$	—
2022
Beginning Balance	$	848,565	$	(29,407)	$	(24,558)	$	794,600	$	59,784
Net income	—		—		46,388		46,388		803
Other comprehensive income	—		16,923		—		16,923		—
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 (loss) / income	—		—		(1,756)		(1,756)		804
Other comprehensive income			20,283				20,283		—
Preferred stock dividends	—		—		—		—		(804)
Distributions to shareholders(2)	(25,297)		—		(8,827)		(34,124)		—
Other	27		—		—		27		—
Balance at June 30, 2022	$	823,321	$	7,799	$	(24,558)	$	806,562	$	59,784
Net income	—		—		24,035		24,035		803
Other comprehensive income	—		14,494		—		14,494		—
Preferred stock dividends	—		—		—		—		(803)
Distributions to shareholders(2)	(8,022)		—		(24,035)		(32,057)		—
Other	29		—		—		29		—
Balance at September 30, 2022	$	815,328	$	22,293	$	(24,558)	$	813,063	$	59,784
1) I (1) All of AES Indiana's preferred stock was redeemed on December 30, 2022.
(2) IPALCO made return of capital payments of $46.5 million and $33.3 million during the nine months ended September 30, 2023 and 2022, respectively, for the portion of current year distributions to shareholders in excess of current year net income at the time of distribution.

See Notes to Condensed Consolidated Financial Statements.

11

IPALCO ENTERPRISES, INC. and SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Three and Nine Months Ended September 30, 2023 and 2022

(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 521,000 retail customers in the city of Indianapolis and neighboring cities, towns and communities, and adjacent rural areas all within the state of Indiana. 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 in May 2021 and 415 MW Petersburg Unit 2 in June 2023, which resulted in 630 MW of total retired economic capacity at this station. AES Indiana plans to convert the remaining two coal units at Petersburg to natural gas by the end of 2025 (for further discussion, see Note 2, "Regulatory Matters - IRP Filings and Replacement Generation - 2022 IRP" to IPALCO’s 2022 Form 10-K). The second largest station, Harding Street, uses natural gas and fuel oil to power steam and 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 peaking station that uses natural gas to power combustion turbines. As of September 30, 2023, AES Indiana’s net electric generation capacity for winter is 3,070 MW and net summer capacity is 2,925 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"). As amended in December 2022 and approved by the IURC in August 2023, the Hardy Hills Solar Project is now expected to be completed in 2024. On August 31, 2023, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 2, LLC, completed the acquisition of Petersburg Energy Center, LLC, including the development of a 250 MW solar and 180 MWh energy storage facility (the "Petersburg Energy Center Project"). As amended in October 2022 and approved by the IURC in May 2023, the Petersburg Energy Center Project is now expected to be completed in 2025.

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 nine months ended September 30, 2023 are not necessarily indicative of expected results for the year ending December 31, 2023. The accompanying condensed consolidated financial statements are unaudited and should be read in conjunction with the 2022 audited consolidated financial statements and notes thereto, which are included in IPALCO's 2022 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 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

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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 AROs and employee benefits.

Reclassifications

Certain immaterial amounts from prior periods have been reclassified to conform to the current year presentation.

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:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	21,537	$	201,548
Restricted cash (included in Prepayments and other current assets)	5		5
Total cash, cash equivalents and restricted cash	$	21,542	$	201,553

Accounts Receivable and Allowance for Credit Losses

The following table summarizes our accounts receivable balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Accounts receivable, net
Customer receivables	$	110,746	$	125,540
Unbilled revenues	54,219		74,488
Amounts due from affiliates	3,742		239
Other	16,680		17,373
Allowance for credit losses	(1,064)		(1,117)
Total accounts receivable, net	$	184,323	$	216,523

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
$ in Thousands	2023		2022
Allowance for credit losses:
Beginning balance	$	1,117	$	647
Current period provision	5,536		4,046
Write-offs charged against allowances	(6,940)		(5,049)
Recoveries collected	1,351		1,201
Ending Balance	$	1,064	$	845

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

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economic conditions are expected to impact collectability, as applicable, of our receivable balance. Amounts are written off when reasonable collections efforts have been exhausted.

Inventories

The following table summarizes our inventories balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Inventories
Fuel	$	80,162	$	60,497
Materials and supplies, net	66,234		63,111
Total inventories	$	146,396	$	123,608

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 nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
	2023		2022
	(In Thousands)
Balance as of January 1	$	218,729	$	189,509
Liabilities incurred	656		1,362
Liabilities settled	(9,946)		(20,421)
Revisions to cash flow and timing estimates	—		23,229
Accretion expense	7,352		6,169
Balance as of September 30	$	216,791	$	199,848

AES Indiana recorded adjustments to its ARO liabilities of $0.0 million and $23.2 million for the nine months ended September 30, 2023 and 2022, respectively, primarily to reflect revisions to cash flow and timing estimates due to increases to estimated ash pond closure costs and accelerated landfill closure dates. As of September 30, 2023 and December 31, 2022, 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 2022 Form 10-K.

AFUDC

In accordance with the Uniform System of Accounts prescribed by FERC, AES Indiana capitalizes an allowance for the net cost of funds (interest on borrowed funds and a reasonable rate of return on equity funds) used for construction purposes during the period of construction with a corresponding credit to income. During the three and nine months ended September 30, 2023, AFUDC equity was $3.1 million and $7.1 million, respectively, and AFUDC debt was $3.8 million and $9.5 million, respectively. During the three and nine months ended September 30, 2022, AFUDC equity was $1.4 million and $4.8 million, respectively, and AFUDC debt was $2.5 million and $5.8 million, respectively.

Intangible Assets

Finite-lived intangible assets include capitalized software and project development intangible assets amortized over their useful lives. Capitalized software of $252.3 million and $205.9 million and its corresponding accumulated amortization of $116.7 million and $107.2 million is recorded as of September 30, 2023 and December 31, 2022,

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respectively. Amortization expense for capitalized software was $9.7 million and $7.6 million for the nine months ended September 30, 2023 and 2022, respectively. These capitalized software intangible assets have a 7 year-weighted average amortization period, and the estimated amortization expense is approximately $40.7 million over the next 5 years ($8.5 million in 2024, $8.4 million in 2025, $8.4 million in 2026, $7.7 million in 2027 and $7.7 million in 2028). Project development intangible assets were $84.1 million and $39.5 million as of September 30, 2023 and December 31, 2022, respectively. These project development intangible assets have a 28 year-weighted average amortization period, and the estimated amortization expense is approximately $11.6 million over the next 5 years ($1.0 million in 2024, $1.3 million in 2025, $3.1 million in 2026, $3.1 million in 2027 and $3.1 million in 2028).

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of AOCI / (AOCL) by component during the three and nine months ended September 30, 2023 and 2022 are as follows (in Thousands):

Details about AOCI / (AOCL) components	Affected line item in the Condensed Consolidated Statements of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Net losses on cash flow hedges (Note 4):	Interest expense	$	1,807	$	1,807	$	5,421	$	5,421
	Income tax effect	(449)		(449)		(1,348)		(1,348)
Total reclassifications for the period, net of income taxes		$	1,358	$	1,358	$	4,073	$	4,073

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 nine months ended September 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.

Related Party Transactions

In the second quarter of 2023, AES Indiana engaged a vendor that is a related party through a competitive RFP process as part of its replacement capacity resource construction projects. AES Indiana had payments of $29.8 million to this vendor during the nine months ended September 30, 2023.

New Accounting Pronouncements Adopted in 2023

We have assessed and determined that the new accounting pronouncements adopted did not have a material impact on the Company's Financial Statements.

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New Accounting Pronouncements Issued But Not Yet Effective

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

ASU Number and Name	Description	Date of Adoption	Effect on the Financial Statements upon adoption
2023-06 Disclosure Improvements: Codification Amendments in Response to the SEC’s Disclosure Update and Simplification Initiative	In U.S. Securities and Exchange Commission (SEC) Release No. 33-10532, Disclosure Update and Simplification, issued August 17, 2018, the SEC referred certain of its disclosure requirements that overlap with, but require incremental information to, generally accepted accounting principles (GAAP) to the FASB for potential incorporation into the Codification. The amendments in this Update are the result of the Board’s decision to incorporate into the Codification 14 of the 27 disclosures referred by the SEC. The amendments in this Update represent changes to clarify or improve disclosure and presentation requirements of a variety of Topics. Many of the amendments allow users to more easily compare entities subject to the SEC’s existing disclosures with those entities that were not previously subject to the SEC’s requirements. Also, the amendments align the requirements in the Codification with the SEC’s regulations.	The effective date for each amendment will be the date on which the SEC's removal of that related disclosure becomes effective, with early adoption prohibited.	The Company is currently evaluating the impact of adopting the standard on its Financial Statements.

2. REGULATORY MATTERS

Regulatory Rate Review

AES Indiana filed a petition with the IURC on June 28, 2023, for authority to increase its basic rates and charges to cover the rising operational costs and needs associated with continuing to serve its customers safely and reliably. The factors leading to AES Indiana's first base rate increase request in five years include inflationary impacts on operations and maintenance expenses, investments in the transmission and distribution systems, and modernization of its customer systems. AES Indiana is also seeking recovery of increased costs to support its vegetation management plan, which covers the removal of overhang and tree trimming in its service territory. The Company also seeks to better align depreciation expense with the period in which the generation plants provide service to customers and remove operational costs of the retired Petersburg units from rates. AES Indiana's proposed revenue increase is $134 million annually, or 8.9%. A hearing on this petition is expected to be held in December 2023. We expect to receive an order from the IURC and place new rates into effect by the end of the second quarter of 2024.

DSM

AES Indiana filed a petition with the IURC on May 26, 2023 asking for approval of a one year DSM interim plan. A hearing was held in September 2023, and we expect the IURC to issue an order on this proceeding during the fourth quarter of 2023.

Replacement Generation

Hardy Hills Solar Project

In December 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 1, LLC, closed on an agreement for the acquisition and construction of the 195 MW Hardy Hills Solar Project to be developed in Clinton County, Indiana. In December 2022, the agreement was amended to revise the project schedule, including shifting the completion date to 2024, and adjusting for increased project costs. On January 13, 2023, AES Indiana filed a petition with the IURC for approval of these revisions, which was approved in August 2023.

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Petersburg Energy Center Project

In July 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 2, LLC, executed an agreement for the acquisition and construction of a 250 MW solar and 180 MWh energy storage facility to be developed in Pike County, Indiana. In October 2022, the agreement was amended to revise the project schedule, including shifting the completion date to 2025, and adjusting for increased project costs. On December 22, 2022, AES Indiana filed a petition with the IURC for approval of these revisions, which was approved in May 2023. On August 31, 2023, AES Indiana closed on the agreement for the acquisition and construction of the Petersburg Energy Center Project. This transaction was accounted for as an asset acquisition of a variable interest entity that did not meet the definition of a business; therefore, the individual assets were recorded at their fair values. Total net assets of $48.7 million were recorded in the accompanying Consolidated Balance Sheets associated with the transaction, primarily consisting of project development intangible assets (see Note 1, "Overview and Summary of Significant Accounting Policies - Intangible Assets" for further information).

Pike County BESS Project

In June 2023, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 3, LLC, executed an agreement for the construction of the 200 MW Pike County BESS project to be developed at the AES Indiana Petersburg Plant site in Pike County, Indiana. On July 19, 2023, AES Indiana filed a petition and case-in-chief with the IURC seeking approval for a Clean Energy Project and associated timely cost recovery under Indiana Code for this project. A hearing for this case was held in October 2023, and IURC review is expected to be completed during the fourth quarter of 2023. Subject to IURC approval, the Pike County BESS project is expected to be completed in 2024.

Hoosier Wind Project

On July 5, 2023, AES Indiana filed a Notice of Intent with the IURC to request approval of a Clean Energy Project and for issuance of a CPCN for the Hoosier Wind Project acquisition. The proposed Project is the acquisition of Hoosier Wind Project, which is an existing 106 MW wind facility located in Benton County, Indiana. The Company executed the Purchase Agreement on July 28, 2023. A CPCN for this case was filed in early August 2023, and a hearing was held in October 2023. IURC review is expected to be completed during the fourth quarter of 2023.

EV Portfolio Program

On January 27, 2023, AES Indiana filed with the IURC a request to approve its EV Portfolio and associated accounting and ratemaking treatment. The EV Portfolio includes two separate parts: (1) a set of EV specific rates, tariffs, and alternative pricing structures, and (2) a set of Public Use EV Pilot Programs. The EV portfolio is designed to produce net benefits for all customers through new retail margins and grid optimization. The projected costs to successfully implement the services proposed in the EV Portfolio are estimated at $16.2 million over the three-year period. AES Indiana requested approval to defer as a regulatory asset and recover in future base rates the cost necessary to implement the EV Portfolio, including carrying charges. A hearing on this request was held in July 2023, and we expect the IURC to issue an order on this request during the fourth quarter of 2023.

Storm Outage Restoration Inquiry

On July 11, 2023, the Indiana Office of Utility Consumer Counselor (“OUCC”) and the Citizens Action Coalition (“CAC”) filed a Joint Petition through which they requested the IURC open an investigation into AES Indiana’s practices and procedures regarding storm outage restoration. A technical conference was held on October 2, 2023, to discuss AES Indiana’s response to outages and storm restoration; particularly the storms that occurred between June 29, 2023 and July 2, 2023.

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 2022 Form 10-K.

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Financial Assets and Liabilities

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 (expense) / income, 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.

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 September 30, 2023 and December 31, 2022 measured on a recurring basis and the respective category within the fair value hierarchy for IPALCO was determined as follows (In Thousands):

	Fair Value as of September 30, 2023								Fair Value as of December 31, 2022
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Financial assets:
VEBA investments:
Money market funds	$	74	$	—	$	—	$	74	$	5	$	—	$	—	$	5
Mutual funds	3,563		—		—		3,563		3,223		—		—		3,223
Total VEBA investments	3,637		—		—		3,637		3,228		—		—		3,228
FTRs	—		—		2,351		2,351		—		—		7,545		7,545
Interest rate hedges	—		21,922		—		21,922		—		12,172		—		12,172
Total financial assets measured at fair value	$	3,637	$	21,922	$	2,351	$	27,910	$	3,228	$	12,172	$	7,545	$	22,945

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The following table presents a reconciliation of financial instruments, measured at fair value on a recurring basis, classified as Level 3 in the fair value hierarchy for the periods ending (In Thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Beginning Balance	$	3,294	$	14,527	$	7,545	$	1,235
Issuances	—		—		3,624		15,338
Settlements	(943)		(2,792)		(8,818)		(4,838)
Ending Balance	$	2,351	$	11,735	$	2,351	$	11,735

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:  

	September 30, 2023				December 31, 2022
	Face Value		Fair Value		Face Value		Fair Value
	(In Thousands)
Fixed-rate	$	3,033,800	$	2,730,357	$	3,033,800	$	2,775,644
Variable-rate	75,000		75,000		—		—
Total indebtedness	$	3,108,800	$	2,805,357	$	3,033,800	$	2,775,644

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

•unamortized deferred financing costs of $25.2 million and $26.3 million at September 30, 2023 and December 31, 2022, respectively; and

•unamortized discounts of $6.8 million and $7.1 million at September 30, 2023 and December 31, 2022, 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 2022 Form 10-K.

At September 30, 2023, AES Indiana's outstanding derivative instruments were as follows:

Commodity	Accounting Treatment (a)	Unit	Notional (in thousands)		Sales (in thousands)		Net Notional (in thousands)
Interest rate hedges	Designated	USD	$	400,000	$	—	$	400,000
FTRs	Not Designated	MWh	6,264		—		6,264

(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

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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 September 30,				Interest Rate Hedges for the Nine Months Ended September 30,
$ in thousands (net of tax)	2023		2022		2023		2022
Beginning accumulated derivative gain (loss) in AOCI / (AOCL)	$	24,827	$	7,799	$	22,269	$	(29,407)
Net gains associated with current period hedging transactions	7,482		13,136		7,325		47,627
Net losses reclassified to interest expense, net of tax	1,358		1,358		4,073		4,073
Ending accumulated derivative gain in AOCI	$	33,667	$	22,293	$	33,667	$	22,293
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)	12

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 Condensed 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 net realized losses of $0.0 million and $0.2 million for the three and nine months ended September 30, 2023. There were net realized gains of $0.0 million and $1.3 million related to forward power contracts for the three and nine months ended September 30, 2022.

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 Condensed 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 September 30, 2023 and December 31, 2022, 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	September 30, 2023		December 31, 2022
FTRs	Not a Cash Flow Hedge	Derivative assets, current	$	2,351	$	7,545
Interest rate hedges	Cash Flow Hedge	Derivative assets, current	$	21,922	$	—
Interest rate hedges	Cash Flow Hedge	Derivative assets, non-current	$	—	$	12,172

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5. DEBT

Long-Term Debt

The following table presents our long-term debt:

		September 30,		December 31,
Series	Due	2023		2022
		(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
5.65%	December 2032	350,000		350,000
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		(6,499)		(6,651)
Deferred financing costs		(19,338)		(20,362)
Total AES Indiana first mortgage bonds		2,127,963		2,126,787
Total Long-term Debt – AES Indiana		2,127,963		2,126,787
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		(346)		(425)
Deferred financing costs		(4,896)		(5,912)
Total Long-term Debt – IPALCO Enterprises, Inc.		874,758		873,663
Total Consolidated IPALCO Long-term Debt		3,002,721		3,000,450
Less: Current Portion of Long-term Debt		404,273		—
Net Consolidated IPALCO Long-term Debt		$	2,598,448	$	3,000,450

(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.

Line of Credit

As of September 30, 2023 and December 31, 2022, AES Indiana had $75.0 million and $0.0 million in outstanding borrowings under the committed Credit Agreement, respectively.

IPALCO’s Senior Secured Notes

IPALCO has $405 million of 3.70% Senior Secured Notes due September 1, 2024 ("2024 IPALCO Notes"). Although current liquid funds are not sufficient to repay the collective amounts due under the 2024 IPALCO Notes at maturity, the Company believes it will be able to refinance the 2024 IPALCO Notes based on conversations with investment bankers, which currently indicate more than adequate demand for new IPALCO debt at its current credit ratings, and considering the Company's previous successful debt issuances.

21

6. INCOME TAXES

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 9.7% and 12.2% for the three and nine months ended September 30, 2023, respectively, as compared to 19.5% and 20.5% for the three and nine months ended September 30, 2022, 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 nine months ended September 30, 2023, was calculated using the estimated annual effective income tax rate for 2023 of 12.2% 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 the net periodic benefit cost / (credit) of the Pension Plans combined:

	For the Three Months Ended				For the Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(In Thousands)				(In Thousands)
Components of net periodic benefit cost / (credit):
Service cost	$	1,297	$	2,238	$	3,892	$	6,714
Interest cost	7,455		4,530		22,365		13,570
Expected return on plan assets	(8,277)		(8,914)		(24,830)		(26,747)
Amortization of prior service cost	543		647		1,629		1,942
Amortization of actuarial loss	1,536		603		4,608		1,815
Net periodic benefit cost / (credit)	$	2,554	$	(896)	$	7,664	$	(2,706)

The components of net periodic benefit cost / (credit) other than service cost are included in "Other (expense) / 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 $3.2 million at September 30, 2023 and December 31, 2022, respectively, were not material to the Financial Statements in the periods covered by this report.

22

8. COMMITMENTS AND CONTINGENCIES

Contingencies

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 September 30, 2023 and December 31, 2022, total legal loss contingencies accrued were $0.2 million and $0.1 million, respectively, which primarily related to personal injury litigation. The legal loss contingencies and settlement related accruals are included in "Accrued and other current liabilities" and "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. 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.

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.

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 CCR; 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.

23

9. BUSINESS SEGMENTS

IPALCO manages its business through one reportable operating segment, the Utility segment. The primary segment performance measure is income / (loss) before income tax as management has concluded that this measure best reflects the underlying business performance of IPALCO and is the most relevant measure considered in IPALCO's internal evaluation of the financial performance of its segment. The Utility segment is comprised of AES Indiana, a vertically integrated electric utility. with all other nonutility business activities aggregated separately. See Note 1, "Overview and Summary of Significant Accounting Policies" for further information on AES Indiana. The “Other” nonutility category primarily includes the 2024 IPALCO Notes and 2030 IPALCO Notes and related interest expense, balances 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
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	402,887	$	—	$	402,887	$	494,194	$	—	$	494,194
Depreciation and amortization	$	72,021	$	—	$	72,021	$	66,810	$	—	$	66,810
Interest expense	$	23,502	$	10,969	$	34,471	$	21,697	$	10,933	$	32,630
Income/(loss) before income tax	$	49,887	$	(10,654)	$	39,233	$	42,032	$	(11,174)	$	30,858
	Nine Months Ended						Nine Months Ended
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	1,290,580	$	—	$	1,290,580	$	1,307,919	$	—	$	1,307,919
Depreciation and amortization	$	212,292	$	—	$	212,292	$	199,096	$	—	$	199,096
Interest expense	$	71,604	$	32,906	$	104,510	$	63,703	$	32,849	$	96,552
Income/(loss) before income tax	$	104,005	$	(32,790)	$	71,215	$	122,780	$	(33,429)	$	89,351
	As of September 30, 2023						As of December 31, 2022
	Utility		Other		Total		Utility		Other		Total
Total assets	$	5,684,275	$	49,014	$	5,733,289	$	5,559,977	$	29,237	$	5,589,214

24

10. REVENUES

Revenues are primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenues are 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. Revenues are recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities. Please see Note 13, “Revenues” to IPALCO’s 2022 Form 10-K for further discussion of our retail, wholesale and miscellaneous revenues.

AES Indiana’s revenues from contracts with customers were $393.9 million and $486.3 million for the three months ended September 30, 2023 and 2022, respectively, and $1,265.0 million and $1,285.5 million for the nine months ended September 30, 2023 and 2022, respectively. The following table presents our revenues from contracts with customers and other revenues (in thousands):

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2023		2022		2023		2022
Retail Revenues
Retail revenues from contracts with customers:
Residential	$	162,531	$	172,623	$	515,920	$	511,515
Small commercial and industrial	58,777		62,764		186,313		183,356
Large commercial and industrial	156,995		169,777		489,190		457,723
Public lighting	2,369		2,478		7,453		7,230
Other (1)	4,253		4,645		13,286		13,430
Total retail revenues from contracts with customers	384,925		412,287		1,212,162		1,173,254
Alternative revenues programs	7,877		7,457		23,153		20,381
Wholesale Revenues
Wholesale revenues from contracts with customers:	7,794		67,374		41,489		100,691
Miscellaneous Revenues
Capacity revenues	—		4,999		8,155		6,752
Transmission and other revenues	1,221		1,610		3,204		4,805
Total miscellaneous revenues from contracts with customers	1,221		6,609		11,359		11,557
Other miscellaneous revenues (2)	1,070		467		2,417		2,036
Total Revenues	$	402,887	$	494,194	$	1,290,580	$	1,307,919

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

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

The balances of receivables from contracts with customers were $167.6 million and $198.3 million as of September 30, 2023 and December 31, 2022, respectively. Payment terms for all receivables from contracts with customers typically do not extend beyond 30 days, unless a customer qualifies for payment extension.

25

11. LEASES

Lessor

The Company is the lessor under operating leases for land, office space and operating equipment. Lease receipts from such contracts are recognized as operating lease revenues on a straight-line basis over the lease term whereas contingent rentals are recognized when earned.

The following table presents lease revenues from operating leases in which the Company is the lessor for the periods indicated (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Total lease revenues	$	455	$	274	$	1,275	$	880

The following table presents the underlying gross assets and accumulated depreciation of operating leases included in Property, plant and equipment, net for the periods indicated (in thousands):

Property, Plant and Equipment, Net	September 30, 2023		December 31, 2022
Gross assets	$	4,341	$	4,334
Less: Accumulated depreciation	(1,181)		(1,060)
Net assets	$	3,160	$	3,274

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 September 30, 2023 or December 31, 2022, respectively.

The following table shows the future lease receipts as of September 30, 2023 for the remainder of 2023 through 2027 and thereafter (in thousands):

	Operating Leases
2023	$	136
2024	544
2025	553
2026	554
2027	554
Thereafter	1,245
Total	$	3,586

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

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

FORWARD-LOOKING INFORMATION

The following discussion may contain forward-looking statements regarding us, our business, prospects and our results of operations that are subject to certain risks and uncertainties posed by many factors and events that could cause our actual business, prospects and results of operations to differ materially from those that may be anticipated by such forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those described in “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in IPALCO’s 2022 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 IPALCO's 2022 Form 10-K.

EXECUTIVE SUMMARY

Compared with the same periods in the prior year, the results for the three months ended September 30, 2023 reflect higher income before income tax of $8.4 million, or 27.1% and the results for the nine months ended September 30, 2023 reflect lower income before income tax of $18.1 million, or 20.3%, primarily due to factors including, but not limited to:

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
$ in millions	2023 vs. 2022		2023 vs. 2022
Decrease in retail margin primarily due to lower volumes driven by weather and lower demand	$	(7.1)	$	(45.7)
Decrease due to higher defined benefit plan costs driven by increase in interest cost	(4.4)		(13.1)
Decrease due to higher depreciation expense from additional assets placed in service and higher amortization of regulatory assets	(5.2)		(13.2)
Decrease due to impact of lower NOx allowance pricing on retail margin	(7.6)		(7.3)
Increase due to a charge to power purchased costs recorded in the prior period resulting from settlement of the FAC sub-docket on the Eagle Valley CCGT extended outage	27.8		27.8
Increase in TDSIC rider revenues	6.5		18.9
(Decrease) / increase driven by (higher) / lower contracted services expenses primarily due to higher / (lower) generation maintenance and outage costs	(2.7)		6.7
Increase due to lower health insurance and disability expense	0.6		5.5
Other	0.5		2.3
Net change in income before income tax	$	8.4	$	(18.1)

See "Results of Operations" below for further discussion.

27

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								Nine Months Ended
	September 30,								September 30,
$ in Thousands	2023		2022		$ Change		% Change		2023		2022		$ Change		% Change
REVENUES	$	402,887	$	494,194	$	(91,307)	(18.5)	%	$	1,290,580	$	1,307,919	$	(17,339)	(1.3)	%
OPERATING COSTS AND EXPENSES:
Fuel	96,698		188,437		(91,739)		(48.7)	%	411,864		392,497		19,367		4.9	%
Power purchased	35,748		57,386		(21,638)		(37.7)	%	122,410		151,891		(29,481)		(19.4)	%
Operation and maintenance	120,858		116,969		3,889		3.3	%	356,386		367,525		(11,139)		(3.0)	%
Depreciation and amortization	72,021		66,810		5,211		7.8	%	212,292		199,096		13,196		6.6	%
Taxes other than income taxes	6,359		5,348		1,011		18.9	%	19,779		27,664		(7,885)		(28.5)	%
Other, net	—		—		—		—	%	—		(3,201)		3,201		(100.0)	%
Total operating costs and expenses	331,684		434,950		(103,266)		(23.7)	%	1,122,731		1,135,472		(12,741)		(1.1)	%
OPERATING INCOME	71,203		59,244		11,959		20.2	%	167,849		172,447		(4,598)		(2.7)	%
OTHER (EXPENSE) / INCOME, NET:
Allowance for equity funds used during construction	3,134		1,408		1,726		122.6	%	7,089		4,782		2,307		48.2	%
Interest expense	(34,471)		(32,630)		(1,841)		5.6	%	(104,510)		(96,552)		(7,958)		8.2	%
Other (expense) / income, net	(633)		2,836		(3,469)		(122.3)	%	787		8,674		(7,887)		(90.9)	%
Total other expense, net	(31,970)		(28,386)		(3,584)		12.6	%	(96,634)		(83,096)		(13,538)		16.3	%
INCOME BEFORE INCOME TAX	39,233		30,858		8,375		27.1	%	71,215		89,351		(18,136)		(20.3)	%
Less: income tax expense	3,802		6,020		(2,218)		(36.8)	%	8,663		18,274		(9,611)		(52.6)	%
NET INCOME	35,431		24,838		10,593		42.6	%	62,552		71,077		(8,525)		(12.0)	%
Less: dividends on preferred stock	—		803		(803)		(100.0)	%	—		2,410		(2,410)		(100.0)	%
NET INCOME APPLICABLE TO COMMON STOCK	$	35,431	$	24,035	$	11,396	47.4	%	$	62,552	$	68,667	$	(6,115)	(8.9)	%

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Revenues

Revenues during the three and nine months ended September 30, 2023 decreased $91.3 million and $17.3 million, respectively, compared to the same periods in 2022, which resulted from the following changes (dollars in thousands):

	Three Months Ended							Nine Months Ended
	September 30,							September 30,
	2023		2022		$ Change		% Change	2023		2022		$ Change		% Change
Revenues:
Retail revenues	$	392,802	$	419,744	$	(26,942)	(6.4)%	$	1,235,315	$	1,193,635	$	41,680	3.5%
Wholesale revenues	7,794		67,374		(59,580)		(88.4)%	41,489		100,691		(59,202)		(58.8)%
Miscellaneous revenues	2,291		7,076		(4,785)		(67.6)%	13,776		13,593		183		1.3%
Total revenues	$	402,887	$	494,194	$	(91,307)	(18.5)%	$	1,290,580	$	1,307,919	$	(17,339)	(1.3)%
Heating degree days:
Actual	6		70		(64)		(91.4)%	2,730		3,353		(623)		(18.6)%
30-year average	51		55					3,285		3,313
Cooling degree days:
Actual	788		879		(91)		(10.4)%	1,097		1,292		(195)		(15.1)%
30-year average	802		798					1,152		1,147

The following table presents additional data on kWh sold:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2023	2022	kWh Change	% Change		2023	2022	kWh Change	% Change
kWh Sales (In Millions):
Residential	1,291	1,335	(44)	(3.3)	%	3,657	4,042	(385)	(9.5)	%
Small commercial and industrial	459	470	(11)	(2.3)	%	1,308	1,387	(79)	(5.7)	%
Large commercial and industrial	1,654	1,692	(38)	(2.2)	%	4,547	4,650	(103)	(2.2)	%
Public lighting	4	4	—	—	%	12	13	(1)	(7.7)	%
Sales – retail customers	3,408	3,501	(93)	(2.7)	%	9,524	10,092	(568)	(5.6)	%
Wholesale	195	709	(514)	(72.5)	%	1,181	1,241	(60)	(4.8)	%
Total kWh sold	3,603	4,210	(607)	(14.4)	%	10,705	11,333	(628)	(5.5)	%

29

The following graph shows the percentage changes in weather-normalized and actual retail electric sales volumes by customer class for the three months ended September 30, 2023 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 nine months ended September 30, 2023 as compared to the same period in the prior year:

30

During the three months ended September 30, 2023, revenues decreased $91.3 million to $402.9 million compared to $494.2 million in the same period of the prior year, and during the nine months ended September 30, 2023, revenues decreased $17.3 million to $1,290.6 million compared to $1,307.9 million in the same period of the prior year. These changes were primarily the result of changes in the components of revenues shown below:

$ in millions		Three Months Ended September 30, 2023 vs. 2022		Nine Months Ended September 30, 2023 vs. 2022
Retail revenues:
	Volume:
	Net decrease in the volume of kWh sold primarily due to weather and demand in our service territory versus the comparable period.	$	(11.1)	$	(69.7)
	Price:
	Net (decrease) / increase in the weighted average price of retail kWh sold primarily due to (lower) / higher fuel revenues, as well as higher TDSIC and Off System Sales Margin rider revenues.	(15.9)		108.8
	Other:	0.1		2.6
	Net change in retail revenues	(26.9)		41.7
Wholesale revenues:
	Volume:
	Net 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.	(48.8)		(4.8)
	Price:
	Net decrease 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.	(10.8)		(54.4)
	Net change in wholesale revenues	(59.6)		(59.2)
Miscellaneous revenues
	Primarily due to (decrease) / increase in capacity revenues of $(5.0) million and $1.4 million for the three and nine months ended September 30, 2023 compared to the same periods in the prior year, respectively, due to recent MISO auction results.	(4.8)		0.2
Net change in revenues		$	(91.3)	$	(17.3)

31

Operating Costs and Expenses

The following table illustrates our changes in Operating costs and expenses during the three and nine months ended September 30, 2023, respectively, compared to the same periods in 2022 (in thousands):

	Three Months Ended								Nine Months Ended
	September 30,								September 30,
	2023		2022		$ Change		% Change		2023		2022		$ Change		% Change
Operating costs and expenses:
Fuel	$	96,698	$	188,437	$	(91,739)	(48.7)	%	$	411,864	$	392,497	$	19,367	4.9	%
Power purchased	35,748		57,386		(21,638)		(37.7)	%	122,410		151,891		(29,481)		(19.4)	%
Operation and maintenance	120,858		116,969		3,889		3.3	%	356,386		367,525		(11,139)		(3.0)	%
Depreciation and amortization	72,021		66,810		5,211		7.8	%	212,292		199,096		13,196		6.6	%
Taxes other than income taxes	6,359		5,348		1,011		18.9	%	19,779		27,664		(7,885)		(28.5)	%
Other, net	—		—		—		—		—		(3,201)		3,201		(100.0)	%
Total operating costs and expenses	$	331,684	$	434,950	$	(103,266)	(23.7)	%	$	1,122,731	$	1,135,472	$	(12,741)	(1.1)	%

Fuel

The (decrease) / increase in fuel costs of $(91.7) million and $19.4 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions		Three Months Ended September 30, 2023 vs. 2022		Nine Months Ended September 30, 2023 vs. 2022
Volume:
	Coal	$	(28.4)	$	(63.4)
	Natural gas	20.8		128.9
	Oil	(0.1)		(0.1)
	Net change in volume	(7.7)		65.4
Price:
	Coal	10.9		15.7
	Natural gas	(74.8)		(187.0)
	Oil	(0.1)		0.1
	Deferred fuel	(20.0)		125.2
	Net change in price	(84.0)		(46.0)
Net change in fuel expense		$	(91.7)	$	19.4

The changes in the price of fuel are reflective of 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.

32

Power Purchased

The decreases in power purchased of $21.6 million and $29.5 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions		Three Months Ended September 30, 2023 vs. 2022		Nine Months Ended September 30, 2023 vs. 2022
Volume:
	Net change in the volume of power purchased primarily due to AES Indiana's generation units running (less)/more frequently, as well as the timing and duration of outages, during these respective periods	$	21.8	$	(27.1)
Price:
	Market prices	(26.3)		(42.5)
	Deferred purchased power	(23.0)		34.1
	Net change in price	(49.3)		(8.4)
Other, net (mostly due to changes in capacity purchases)		5.9		6.0
Net change in power purchased costs		$	(21.6)	$	(29.5)

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

The Eagle Valley CCGT was on unplanned outage from late April 2021 until mid-March 2022, impacting several FAC periods. The IURC initiated a sub-docket in FAC-133 (IURC Cause No. 38703-FAC-133 S1) to examine the impact of the Eagle Valley extended outage, which was settled in October 2022. A $27.8 million charge was recorded in the third quarter of 2022 resulting from the settlement of the FAC sub-docket of the Eagle Valley CCGT unplanned outage.

Operation and Maintenance

The increase / (decrease) in Operation and maintenance of $3.9 million and $(11.1) million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions	Three Months Ended September 30, 2023 vs. 2022		Nine Months Ended September 30, 2023 vs. 2022
Increase / (decrease) in contracted services expenses primarily due to higher / (lower) generation maintenance and outage costs	$	2.7	$	(6.7)
Decrease in DSM program costs (these program costs are recoverable through customer rates and are offset by a decrease in DSM revenues)	(1.5)		(7.9)
Decrease due to lower health insurance and disability expense	(0.6)		(5.5)
Increase in charges from the Service Company	2.9		8.3
Other, net	0.4		0.7
Net change in operation and maintenance costs	$	3.9	$	(11.1)

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Depreciation and Amortization

The increases in Depreciation and amortization expense of $5.2 million and $13.2 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were mostly attributed to the impact of additional assets placed in service and higher amortization of regulatory assets.

Taxes Other Than Income Taxes

The increase / (decrease) in Taxes other than income taxes of $1.0 million and $(7.9) million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to the following changes:

$ in millions	Three Months Ended September 30, 2023 vs. 2022		Nine Months Ended September 30, 2023 vs. 2022
Decrease due to the repeal of the URT (for further discussion, please see Note 2, "Regulatory Matters - House Bill 1002" to the Financial Statements of IPALCO's 2022 Form 10-K	$	—	$	(11.1)
Increase in property taxes primarily due to increased assessed values	1.1		3.3
Other, net	(0.1)		(0.1)
Net change in taxes other than income taxes	$	1.0	$	(7.9)

Other, Net

The changes in Other, net of $0.0 million and $3.2 million during the three and nine months ended September 30, 2023, 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 (Expense) / Income, Net

The following table illustrates our changes in Other (expense) / income, net during the three and nine months ended September 30, 2023, respectively, compared to the same periods in 2022 (in thousands):

	Three Months Ended								Nine Months Ended
	September 30,								September 30,
	2023		2022		$ Change		% Change		2023		2022		$ Change		% Change
Other (expense) / income, net
Allowance for equity funds used during construction	$	3,134	$	1,408	$	1,726	122.6	%	$	7,089	$	4,782	$	2,307	48.2	%
Interest expense	(34,471)		(32,630)		(1,841)		5.6	%	(104,510)		(96,552)		(7,958)		8.2	%
Other (expense) / income, net	(633)		2,836		(3,469)		(122.3)	%	787		8,674		(7,887)		(90.9)	%
Total other expense, net	$	(31,970)	$	(28,386)	$	(3,584)	12.6	%	$	(96,634)	$	(83,096)	$	(13,538)	16.3	%

Allowance for Equity Funds Used During Construction

The increases in Allowance for equity funds used during construction of $1.7 million and $2.3 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to increased construction activity.

Interest Expense

The increases in Interest expense of $1.8 million and $8.0 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to (i) higher interest expense on debt of $3.0 million and $11.6 million, respectively (mostly due to the debt issuance of $350 million AES Indiana first mortgage bonds in November 2022), partially offset by (ii) increases in the allowance for borrowed funds used during construction of $1.3 million and $3.7 million, respectively.

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Other (Expense) / Income, Net

The decreases in Other (expense) / income, net of $3.5 million and $7.9 million during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year were primarily due to (i) increases in defined benefit plan costs of $4.4 million and $13.1 million, respectively (mostly as a result of higher interest cost), partially offset by (ii) increases in investment income of $1.1 million and $5.3 million, respectively.

Income Tax Expense

The following table illustrates our changes in Income tax expense during the three and nine months ended September 30, 2023, respectively, compared to the same periods of the prior year (in thousands):

	Three Months Ended								Nine Months Ended
	September 30,								September 30,
	2023		2022		$ Change		% Change		2023		2022		$ Change		% Change
Income tax expense	$	3,802	$	6,020	$	(2,218)	(36.8)	%	$	8,663	$	18,274	$	(9,611)	(52.6)	%

The decrease in Income tax expense of $2.2 million during the three months ended September 30, 2023, was primarily driven by a lower estimated annual effective tax rate, partially offset by higher pre-tax income as compared to the comparable period of the prior year.

The decrease in Income tax expense of $9.6 million during the nine months ended September 30, 2023, was primarily driven by a lower estimated annual effective tax rate and lower pre-tax income as compared to the comparable period of the prior year.

KEY TRENDS AND UNCERTAINTIES

During the remainder of 2023 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 and operation and maintenance costs.

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 income, 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 2022 Form 10-K.

Operational

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 June 6, 2022, President Biden issued a Proclamation waiving any tariffs that result from this investigation for a 24-month period. Since President Biden’s Proclamation, suppliers in Southeast Asia have imported panels again to the U.S.

On December 2, 2022, Commerce issued country-wide affirmative preliminary determinations that circumvention had occurred in each of the four South Asian countries. Commerce also evaluated numerous individual companies and issued preliminary determinations that circumvention had occurred with respect to many but not all of these companies. Additionally, Commerce issued a preliminary determination that circumvention would not be deemed to occur for any solar cells and panels imported from the four countries if the wafers were manufactured outside of China or if no more than two out of six specifically identified components were produced in China. On August 18,

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2023, Commerce issued its final determination on the matter and affirmed its preliminary findings in most respects. Additionally, Commerce found that three of the specific companies it investigated were not circumventing.

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 due to supply chain disruptions; 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

Inflation Reduction Act and U.S. Renewable Energy Tax Credits

The Inflation Reduction Act (the “IRA”) was signed into law in the United States in 2022. The IRA includes provisions that are expected to benefit the Company's planned clean energy projects, including increases, extensions and/or new tax credits for wind, solar, and storage. We expect that the extension of the current solar investment tax credits ("ITCs") for projects that satisfy wage and apprenticeship requirements, as well as the "technology neutral" clean electricity production tax credit ("PTC") and ITC will provide incremental benefits for our renewable projects. We do not anticipate realizing any benefit related to the IRA in 2023.

We account for renewable projects according to GAAP, which, when partnering with tax-equity investors to monetize tax benefits, utilizes the HLBV method. This method recognizes the tax-credit value that is transferred to tax equity partners at the time of its creation, which for projects utilizing the ITC, is in the quarter the project begins commercial operation. For projects utilizing the PTC, this value is recognized over 10 years as the facility produces energy.

The implementation of the IRA is expected to require substantial guidance from the U.S. Department of Treasury and other government agencies. While that guidance is pending, there will be uncertainty with respect to the implementation of certain provisions of the IRA.

U.S. Income Tax

The macroeconomic and political environments in the U.S. have changed during 2022 and 2023. This could result in significant impacts to tax law. An example of this is the IRA, which expands and extends incentives related to investment in renewable energy. We continue to evaluate the applicability and effect of the new law on AES Indiana.

Inflation

In the markets in which we operate, there have been higher rates of inflation recently. 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, continues to be volatile into 2023. 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.

Interest Rates

In the U.S. there has been a rise in interest rates recently. From July 1 to September 30, 2023 the yield on 10-year U.S. Treasury Notes rose from 3.84% to 4.57%. Although all of our existing IPALCO and AES Indiana long-term

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debt is at fixed rates, an increase in interest rates can have several impacts on our business. For our existing short-term debt under floating rate structures and any future debt refinancings or future new money financings, rising interest rates will increase future financing costs. Our floating rate debt is currently limited to short-term borrowings under our Credit Agreement. For future IPALCO debt financings, IPALCO manages a hedging program to reduce uncertainty and exposure to future interest rates.

Bipartisan Infrastructure Law (Infrastructure Investment and Jobs Act)

In November 2021, President Biden signed into law the Infrastructure Investment and Jobs Act, which provides for approximately $1.2 trillion of federal spending over the next five years across the United States. The BIL’s energy-related provisions include new federal funding for power grid infrastructure and resiliency investments, new and existing energy efficiency and weatherization programs, electric vehicle infrastructure for public chargers and additional Low Income Home Energy Assistance Program funding. AES Indiana is participating as a sub-recipient for a Department of Energy Office of Energy Efficiency and Renewable Energy Topic 2 award and has identified other potential opportunities associated with the BIL and is submitting concept papers and grants for those that align with its strategy going forward.

Regulatory

Regulatory Rate Review

On June 28, 2023, AES Indiana filed a petition with the IURC for authority to increase its basic rates and charges to cover the rising operational costs and needs associated with continuing to serve its customers safely and reliably. AES Indiana's proposed revenue increase was $134 million annually, or 8.9%. We expect to receive an order from the IURC by the end of the second quarter of 2024.

2022 IRP

AES Indiana filed its 2022 IRP with the IURC in December 2022. The 2022 IRP short-term action plan includes converting the two remaining coal units at Petersburg to natural gas by the end of 2025. Additionally, AES Indiana plans to add up to 1,300 MW of wind, solar, and battery energy storage by 2027. For further discussion, see Note 2, "Regulatory Matters - Replacement Generation" to the Financial Statements of this Form 10-Q and Note 2, "Regulatory Matters - IRP Filings and Replacement Generation" to the Financial Statements included in IPALCO’s 2022 Form 10-K.

Please see Note 2, "Regulatory Matters" to the Financial Statements included in this Form 10-Q and Note 2, “Regulatory Matters” to the Financial Statements included in IPALCO’s 2022 Form 10-K for further discussion of these and other regulatory matters.

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. 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 2022 Form 10-K.

MATS

In April 2012, the EPA’s rule to establish maximum achievable control technology standards for hazardous air pollutants regulated under the CAA emitted from coal and oil-fired electric utilities, known as “MATS”, became effective. AES Indiana management developed and implemented a plan, which was approved by the IURC, to comply with this rule and all four Petersburg units have been and remain in material compliance with the MATS rule since applicable deadlines.

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In June 2015, the U.S. Supreme Court remanded MATS to the D.C. Circuit due to the EPA’s failure to consider costs before deciding to regulate power plants under Section 112 of the CAA and subsequently remanded MATS to the EPA without vacatur. On May 22, 2020, the EPA published a final finding that it is not “appropriate and necessary” to regulate hazardous air pollutant emissions from coal- and oil-fired EGUs (reversing its prior 2016 finding), but that the EPA would not remove the source category from the CAA Section 112(c) list of source categories and would not change the MATS requirements. On March 6, 2023, the EPA published a final rule to revoke its May 2020 finding and reaffirm its 2016 finding that it is appropriate and necessary to regulate these emissions. On April 24, 2023, EPA published the proposed MATS Risk and Technology Review (RTR) Rule to lower certain emissions limits and revise certain other aspects of MATS. We are still reviewing the proposal. However, the existing requirements of MATS and the proposed requirements of MATS RTR Rule would not apply to AES Indiana upon conversion of the remaining two coal-fired units at Petersburg to natural gas.

Further rulemakings and/or proceedings are possible; however, in the meantime, MATS remains in effect. We currently cannot predict the outcome of the regulatory or judicial process, or its impact, if any, on our MATS compliance planning or ultimate costs.

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 December 21, 2022, IDEM

published in the Indiana Register a Second Notice of Comment Period for its proposed CCR rulemaking which would include regulation of CCR through a state permitting program.

The EPA has indicated that they will implement a phased approach to amending the CCR Rule, which is ongoing.

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 its first in a series of proposed and final determinations regarding CCR Part A Rule demonstrations and 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. While AES Indiana has not received 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.

On May 18, 2023, EPA published a proposed rule that would expand the scope of CCR units regulated by the CCR Rule to include inactive surface impoundments at inactive generating facilities as well as additional inactive and closed landfills and certain other accumulations of CCR. We are still reviewing the proposal and it is too early to determine the potential impact.

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The CCR Rule, current or proposed amendments to the CCR Rule, Indiana CCR regulations, 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" and

Note 10, "Commitments and Contingencies - Coal Ash Insurance Litigation" to the Financial Statements of IPALCO’s 2022 Form 10-K for further discussion.

Environmental Wastewater Requirements

In November 2015, the EPA published its final Steam ELG rule to reduce toxic pollutants discharged into waterways by steam-electric power plants through technology applications. In 2020, EPA issued a final rule, known as the 2020 Reconsideration Rule, revising certain aspects of the 2015 ELG rule. Wastewater treatment technologies already installed and operated at Petersburg met the requirements of these rules. Following the 2019 U.S. Court of Appeals vacature and remand of portions of the 2015 ELG rule related to leachate and legacy water, on March 29, 2023, EPA published a proposed rule revising the 2020 Reconsideration Rule. The proposed rule would establish new best available technology economically achievable effluent limits for flue gas desulfurization wastewater, bottom ash treatment water, and combustion residual leachate. It is too early to determine whether any outcome of this proposed rule, litigation or current or future revisions to the ELG rule might have a material impact on our business, financial condition and results of operations.

National Pollutant Discharge Elimination System (NPDES) permits regulate specific industrial wastewater and storm water discharges to the waters of Indiana under Section 402 of the Federal Water Pollution Control Act. In 2017, IDEM issued to Eagle Valley a NPDES permit regulating water discharges associated with operation of its CCGT. As part of the normal course of business, AES Indiana submitted a timely application for renewal for the Eagle Valley NPDES permit, and on March 31, 2023, IDEM issued the renewed NPDES permit. On April 17, 2023, a third party filed an appeal of Eagle Valley’s renewed NPDES permit. AES Indiana contends that the renewed permit was validly issued, and the permit remains in effect. AES Indiana is unable to predict the outcome of the appeal, but depending on the results, it could have an adverse effect on the Company.

In 2017, IDEM also issued to Harding Street a NPDES permit regulating water discharges associated with operation of its natural gas-fired power plant. As part of the normal course of business, AES Indiana submitted a timely application for renewal for the Harding Street NPDES permit, and on May 25, 2023, IDEM issued a proposed NPDES permit for public comment. The proposed permit includes new requirements that could result in the need for AES Indiana to take additional actions to ensure compliance with the proposed permit. It is too early to determine the potential impact, but the permit 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.

Regulation of Water Discharge

The concept of WOTUS defines the geographic reach and authority of the U.S. Army Corps of Engineers and EPA (together, the "Agencies") to regulate streams, wetlands, and other water bodies under the CWA. There have been multiple Supreme Court decisions and dueling regulatory definitions over the past several years concerning the proper standard for how to properly determine whether a wetland or stream that is not navigable is considered a WOTUS. On May 25, 2023, the U.S. Supreme Court rendered a decision (Decision) in the case of Sackett v. Environmental Protection Agency, addressing the definition of WOTUS with regards to the CWA. This decision provides a clear standard that substantially restricts the Agencies' ability to regulate certain types of wetlands and streams. Specifically, under this decision, wetlands that do not have a continuous surface connection with traditional interstate navigable water are not considered a WOTUS and therefore are not federally jurisdictional.

On September 8, 2023, the Agencies published final rule amendments in the Federal Register to amend the final “Revised Definition of ‘Waters of the United States’” rule. This final rule conforms the definition of WOTUS to the definition adopted in the Decision. The Agencies have amended key aspects of the regulatory text to conform the rule to the Decision.

It is too early to determine whether any outcome of litigation or current or future revisions to rules interpreting federal jurisdiction over WOTUS might have a material adverse effect on our results of operations, financial condition and cash flows.

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Climate Change Legislation and Regulation

One byproduct of burning coal and other fossil fuels is the emission of GHGs, including CO2. We face certain risks related to existing and potential international, federal, state, regional and local GHG legislation and regulations,

including risks related to increased capital expenditures or other compliance costs, as well as increased climate change disclosure obligations, which could have a material adverse effect on our results of operations, financial condition and cash flows.

The possible impact of any existing or future international, federal, regional or state GHG legislation, regulations or

proposals will depend on various factors, including but not limited to:

•The geographic scope of legislation and/or regulation (e.g., international, federal, regional, state), which entities are subject to the legislation and/or regulation (e.g., electricity generators, load-serving entities, electricity deliverers, etc.), the enactment date of the legislation and/or regulation and the compliance deadlines set forth therein;

•The level of reductions of GHGs being sought by the regulation and/or legislation (e.g., 10%, 20%, 50%, etc.) and the year selected as a baseline for determining the amount or percentage of mandated GHG reduction (e.g., 10% reduction from 1990 emission levels, 20% reduction from 2000 emission levels, etc.);

•The legislative and/or regulatory structure (e.g., a GHG cap-and-trade program, a carbon tax, GHG emission limits, etc.);

•In any cap-and-trade program, the mechanism used to determine the price of emission allowances or offsets to be auctioned by designated governmental authorities or representatives;

•The price of offsets and emission allowances in the secondary market, including any price floors or price caps on the costs of offsets and emission allowances;

•The operation of and emissions from regulated units;

•The permissibility of using offsets to meet reduction requirements and the requirements of such offsets (e.g., type of offset projects allowed, the amount of offsets that can be used for compliance purposes, any geographic limitations regarding the origin or location of creditable offset projects), as well as the methods required to determine whether the offsets have resulted in reductions in GHG emissions and that those reductions are permanent (i.e., the verification method);

•Whether the use of proceeds of any auction conducted by responsible governmental authorities is reinvested in developing new energy technologies, is used to offset any cost impact on certain energy consumers or is used to address issues unrelated to power;

•How the price of electricity is determined, including whether the price includes any costs resulting from any new climate change legislation and the potential to transfer compliance costs pursuant to legislation, market or contract, to other parties;

•Any impact on fuel demand and volatility that may affect the market clearing price for power;

•The effects of any legislation or regulation on the operation of power generation facilities that may in turn affect reliability;

•The availability and cost of carbon control technology;

•Whether any federal legislation regulating GHG emissions will preclude the EPA from regulating GHG emissions under the CAA or preempt private nuisance suits or other litigation by third parties;

•Any opportunities to change the use of fuel at the generation facilities or opportunities to increase efficiency;

•The extent of any required GHG emissions disclosure requirements in the forthcoming final version of the SEC's proposed 2022 climate change disclosure rule, including potential disclosure of Scope 1-3 GHG emissions; and

•Our ability to recover any resulting costs from our customers and the timing of such recovery.

Except as noted in the discussion below, at this time, we cannot estimate the costs of compliance with existing,

proposed or potential international, federal, state or regional GHG emissions reductions legislation or initiatives due

in part to the fact that many of these proposals are in earlier stages of development and any final laws or

regulations, if adopted, could vary drastically from current proposals. Any international, federal, state or regional

legislation adopted in the U.S. that would require the reduction of GHG emissions could have a material adverse effect on our business and/or results of operations, financial condition and cash flows.

In the past, the U.S. Congress has considered several different draft bills pertaining to GHG legislation, including comprehensive GHG legislation that would impact many industries and more limited legislation focusing only on the

utility and electric generation industry. Although no legislation pertaining to GHG emissions has been passed to date

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by the U.S. Congress, similar legislation may be considered or passed by the U.S. Congress in the future. In

addition, in the past Midwestern state governors (including the Governor of Indiana) and the premier of Manitoba,

Canada committed to reduce GHG emissions through the implementation of a cap-and-trade program pursuant to

the Midwestern Greenhouse Gas Reduction Accord. Though the participating states and province are no longer

pursuing this commitment, similar applicable state or regional initiatives may be pursued in the future.

The final NSPS for CO2 emissions from new, modified and reconstructed fossil-fuel-fired power plants were published in the Federal Register on October 23, 2015. Several states and industry groups challenged the NSPS for

CO2 in the D.C. Circuit Court. On December 20, 2018, the EPA published proposed revisions to the final NSPS for

new, modified and reconstructed coal-fired electric utility steam generating units. The EPA proposed that the Best System of Emissions Reduction (BSER) for these units is highly efficient generation that would be equivalent to

supercritical steam conditions for larger units and sub-critical steam conditions for smaller units, and not partial

carbon capture and sequestration (CCS), which had been the BSER for these units in the 2015 final NSPS. The

EPA did not include revisions for natural-gas combined cycle or simple cycle units in the December 20, 2018

proposal. Challenges to the GHG NSPS remain held in abeyance at this time. On May 23, 2023, EPA published a proposed rule that would establish CO2 emissions limits for certain new fossil-fuel fired stationary combustion turbines that commence construction or are modified after May 23, 2023.

On July 8, 2019, the EPA published the final ACE Rule which would have established CO2 emission rules for existing coal-fired power plants under CAA Section 111(d) and would have 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. However, on January 19, 2021, the D.C. Circuit vacated and remanded to EPA the ACE Rule. Subsequently, on June 30, 2022, the U.S. Supreme Court reversed the judgment of the D.C. Circuit Court and

remanded for further proceedings consistent with its opinion, holding that the “generation shifting” approach in the CPP exceeded the authority granted to EPA by Congress under Section 111(d) of the CAA. As a result of the June 30, 2022 U.S. Supreme Court decision, on October 27, 2022, the D.C. Circuit issued a partial mandate holding pending challenges to the ACE Rule in abeyance while EPA developed a replacement rule.

On May 23, 2023, EPA published a proposed rule that would vacate the ACE Rule, establish emissions guidelines in the form of CO2 emissions limitations for certain existing EGUs and would require states to develop State Plans that establish standards of performance for such EGUs that are at least as stringent as EPA’s emissions guidelines. Depending on various EGU-specific factors, the bases of proposed emissions guidelines range from routine methods of operations to carbon capture and sequestration or co-firing low-GHG hydrogen starting in the 2030s.

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.

On the international level, on December 12, 2015, 195 nations, including the U.S., finalized the text of an

international climate change accord in Paris, France (the “Paris Agreement”), which agreement was signed and

officially entered into on April 22, 2016. The Paris Agreement calls for countries to set their own GHG emissions targets, make these emissions targets more stringent over time and be transparent about the GHG emissions reporting and the measures each country will use to achieve its GHG emissions targets. A long-term goal of the

Paris Agreement is to limit global temperature increase to well below two degrees Celsius from temperatures in the

pre-industrial era. The U.S. withdrawal from the Paris Agreement became effective on November 4, 2020. However,

on January 20, 2021, President Biden signed and submitted an instrument for the U.S. to rejoin the Paris Agreement, which became effective on February 19, 2021. In November 2022, the international community

gathered in Egypt at the 27th Conference to the Parties on the UN Framework Convention on Climate Change

(“COP27”), during which multiple announcements were made, including the establishment of a loss and damage fund to support vulnerable countries dealing with the effects of climate change and certain pledges in the area of

climate finance.

Based on the above, there is some uncertainty with respect to the impact of GHG rules on AES Indiana. The NSPS

will not require us to comply with an emissions standard until we construct a new electric generating unit. We do not

have any planned major modifications of an existing source or plans to construct a new major source which are expected to be subject to these regulations at this time. Furthermore, the EPA, states and other utilities are still

41

evaluating potential impacts of the GHG regulations in our industry. In light of these uncertainties, we cannot predict the impact of the EPA’s current and future GHG regulations on our consolidated results of operations, cash flows,

and financial condition, but it could be material.

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. 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 NOx Ozone Season allowances beginning in 2021.

On June 5, 2023, the EPA published a final Federal Implementation Plan ("FIP") to address air quality impacts with respect to the 2015 Ozone NAAQS. The rule establishes a revised CSAPR NOx Ozone Season Group 3 trading program for 22 states, including Indiana and is expected to become effective during 2023. The FIP also includes enhancements in the revised Group 3 trading program which include a dynamic budget setting process beginning in 2026, annual recalibration of the allowance bank to reflect changes to affected sources, a daily backstop emissions rate limit for certain coal-fired electric generating units beginning in 2024, and a secondary emissions limit prohibiting certain emissions associated with state assurance levels.

At this time, we cannot predict the impact of these rule revisions or potential future legal outcomes, but any such impact could include the need to purchase additional allowances or make operational adjustments or could otherwise be material to our business, financial condition or results of operation. For further discussion, see

"Item 1. Business - Environmental Matters - CSAPR and 2015 Ozone NAAQS FIP" of IPALCO’s 2022 Form 10-K.

Cooling Water Intake Regulations

We use water as a coolant at our generating stations. Under the CWA, cooling water intake structures are required to reflect the BTA for minimizing adverse environmental impact. In 2014, the EPA's final standards became effective to protect fish and other aquatic organisms drawn into cooling water systems at large power plants and other facilities. These standards, based on Section 316(b) of the CWA, require affected facilities to choose amongst seven BTA options to reduce fish impingement. In addition, certain facilities must conduct studies to assist permitting authorities to determine whether and what site-specific controls, if any, would be required to reduce entrainment of aquatic organisms. It is possible this process, which includes permitting and public input, could result in the need to install closed-cycle cooling systems (closed-cycle cooling towers) or other technology. Finally, the standards require that new units added to an existing facility must reduce both impingement and entrainment that achieves one of two alternatives under national BTA standards. AES Indiana’s NPDES permits will be updated with the requirements of this rule, including any source-specific requirements arising from the evaluation process described above. In May 2023, the Indiana Department of Environmental Management rendered proposed impingement and entrainment BTA determinations for Harding Street which may result in the need to install modified traveling screens and a fish handling and return system and also conduct a 2-year entrainment study. As final BTA determinations have not yet been rendered, it is not yet possible to predict the total impacts of this final rule, including any challenges to such final rule and the outcome of any such challenges. However, if additional capital expenditures are necessary, they could be material. We would seek recovery of these capital expenditures; however, there is no guarantee we would be successful.

42

CAPITAL RESOURCES AND LIQUIDITY

Overview

As of September 30, 2023, we had unrestricted cash and cash equivalents of $21.5 million and available borrowing capacity of $275 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, of which $390 million remains available under the order as of September 30, 2023. 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 $400 million remains available under the order as of September 30, 2023. 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 September 30, 2023. 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):

	Nine Months Ended September 30,
	2023		2022		$ Change
Net cash provided by operating activities	$	347,087	$	226,536	$	120,551
Net cash used in investing activities	(534,759)		(393,698)		(141,061)
Net cash provided by financing activities	7,661		170,312		(162,651)
Net change in cash and cash equivalents	(180,011)		3,150		(183,161)
Cash, cash equivalents and restricted cash at beginning of period	201,553		6,917		194,636
Cash, cash equivalents and restricted cash at end of period	$	21,542	$	10,067	$	11,475

Operating Activities

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

	Nine Months Ended September 30,
	2023		2022		$ Change
Net income	$	62,552	$	71,077	$	(8,525)
Depreciation and amortization	212,292		199,096		13,196
Deferred income taxes and investment tax credit adjustments - net	32,735		(11,137)		43,872
Other adjustments to net income	(4,200)		(1,884)		(2,316)
Net income, adjusted for non-cash items	303,379		257,152		46,227
Net change in operating assets and liabilities(1)	43,708		(30,616)		74,324
Net cash provided by operating activities	$	347,087	$	226,536	$	120,551
(1) Refer to the table below for explanations of the variance in operating assets and liabilities.

43

The net change in operating assets and liabilities for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022 was driven by changes in the following (in thousands):

Increase from short-term and long-term regulatory assets and liabilities is primarily due to higher FAC collections in the current year	$	92,523
Increase from accounts receivable driven primarily by the timing of the collections	60,092
Decrease from accounts payable due to the timing of vendor payments	(54,288)
Decrease in accrued taxes due to an increase in deferred taxes mainly driven by the gross tax loss created by Petersburg Unit 2 retirement	(21,394)
Other	(2,609)
Net change in operating assets and liabilities	$	74,324

Investing Activities

Net cash used in investing activities increased $141.1 million for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022, which was primarily driven by (in thousands):

Higher cash outflows for capital expenditures due to higher T&D maintenance related capital expenditures and growth related capital expenditures primarily from TDSIC Plan	$	(85,035)
Higher cash outflows from purchase of intangibles in 2023	(44,650)
Other	(11,376)
Net change in investing activities	$	(141,061)

Financing Activities

Net cash provided by financing activities decreased $162.7 million for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022, which was primarily driven by (in thousands):

Decrease due to proceeds from issuance of AES Indiana Term Loan in June 2022	$	(200,000)
Other	37,349
Net change in financing activities	$	(162,651)

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 2022 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 September 30, 2023
AES Indiana	Revolving	December 2027	$	350.0	$	275.0

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Capital Requirements

Capital Expenditures

Our capital expenditure program, including development and permitting costs, for the three-year period from 2023 through 2025 (including amounts already expended in the first nine months of 2023) is currently estimated to cost approximately $2.6 billion (excluding environmental compliance), and includes estimates as follows (amounts in millions):

	2023		2024		2025		For the three-year period from 2023 through 2025
Transmission and distribution related additions, improvements and extensions	$	168	$	158	$	163	$	489	(1)
TDSIC Plan investments	193		189		212		594		(2)
Power generation and replacement capacity related projects	514		580		356		1,450		(3)
Other miscellaneous equipment	48		28		23		99
Total estimated costs of capital expenditure program	$	923	$	955	$	754	$	2,632
(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 September 30, 2023 were $631.8 million.
(3) Includes spending for AES Indiana's power generation and renewable energy projects

The amounts described in the capital expenditure program above include spending under AES Indiana's 2022 IRP filed with the IURC in December 2022 for the three-year period from 2023 through 2025, including updated capital spending for new agreements executed in 2023 and pending regulatory approval. See Note 2, "Regulatory Matters - IRP Filings and Replacement Generation" to the Financial Statements of IPALCO's 2022 10-K for further discussion. Additionally, estimated capital expenditure spending on environmental compliance costs for the three-year period from 2023 through 2025 includes plans to spend approximately $2.7 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" of IPALCO's 2022 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	BBB	Positive
(a) Ratings relate to IPALCO's Senior Secured Notes.
(b) Ratings relate to AES Indiana's first mortgage bonds.

45

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 nine months of 2023 and 2022, IPALCO paid $66.9 million and $102.0 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 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 revenues 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 IPALCO's 2022 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 IPALCO's 2022 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 nine months ended September 30, 2023.

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 IPALCO's 2022 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 September 30, 2023, 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.

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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, 2022 and Form 10-Q for the quarters ended March 31, 2023 and June 30, 2023 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

There have been no material changes to the risk factors disclosed in Item 1A.—Risk Factors of IPALCO's 2022 Form 10-K. Additional risks and uncertainties also may adversely affect our business and operations, including those discussed in Item 2. – Management's Discussion and Analysis of Financial Condition and Results of Operations in this Form 10-Q.

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.

47

ITEM 6. EXHIBITS

Exhibit No.	Document
31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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)

48

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:	November 2, 2023	/s/ Ahmed Pasha
		Ahmed Pasha
		Vice President and Chief Financial Officer
		(Principal Financial Officer)
Date:	November 2, 2023	/s/ Karin M. Mehringer
		Karin M. Mehringer
		Controller
		(Principal Accounting Officer)

49

EX-31.1

Exhibit 31.1

Certification 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

I, Ken Zagzebski, certify that:

1.I have reviewed this quarterly report on Form 10-Q of IPALCO Enterprises, Inc. (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 2, 2023	/s/ Ken Zagzebski
		Ken Zagzebski
		President and Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification 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

I, Ahmed Pasha, certify that:

1.I have reviewed this quarterly report on Form 10-Q of IPALCO Enterprises, Inc. (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 2, 2023	/s/ Ahmed Pasha
		Ahmed Pasha
		Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification Pursuant to Rule 13a-14(b)/15d-14(b) of the Securities Exchange Act of 1934 and Pursuant to Section 1350 of Chapter 63 of Title 18 of the United States Code as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

The certification set forth below is being submitted in connection with the Quarterly Report on Form 10-Q for the period ended September 30, 2023 (the “Report”) for the purpose of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934 and Section 1350 of Chapter 63 of Title 18 of the United States Code.

Ken Zagzebski, President and Chief Executive Officer of IPALCO Enterprises, Inc. (“IPALCO”), certifies that, to the best of his knowledge:

1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of IPALCO.

Date:	November 2, 2023	/s/ Ken Zagzebski
		Ken Zagzebski
		President and Chief Executive Officer

A signed original of this written statement required by Section 906 has been provided to IPALCO and will be retained by IPALCO and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

Certification Pursuant to Rule 13a-14(b)/15d-14(b) of the Securities Exchange Act of 1934 and Pursuant to Section 1350 of Chapter 63 of Title 18 of the United States Code as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

The certification set forth below is being submitted in connection with the Quarterly Report on Form 10-Q for the period ended September 30, 2023 (the “Report”) for the purpose of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934 and Section 1350 of Chapter 63 of Title 18 of the United States Code.

Ahmed Pasha, Chief Financial Officer of IPALCO Enterprises, Inc. (“IPALCO”), certifies that, to the best of his knowledge:

1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of IPALCO.

Date:	November 2, 2023	/s/ Ahmed Pasha
		Ahmed Pasha
		Vice President and Chief Financial Officer

A signed original of this written statement required by Section 906 has been provided to IPALCO and will be retained by IPALCO and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Cover - shares	9 Months Ended
	Sep. 30, 2023	Nov. 02, 2023
Entity Information [Line Items]
Document Fiscal Year Focus	2023
Entity Central Index Key	0000728391
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	IN
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Sep. 30, 2023
Amendment Flag	false
Document Fiscal Period Focus	Q3
Entity Registrant Name	IPALCO ENTERPRISES, INC.
Entity Tax Identification Number	35-1575582
Entity Address, City or Town	Indianapolis
Entity File Number	1-8644
Entity Address, Address Line One	One Monument Circle
Entity Address, Postal Zip Code	46204
Entity Address, State or Province	IN
City Area Code	317
Local Phone Number	261-8261
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Common Stock, Shares, Outstanding		108,907,318
AES U.S. Investments [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding		89,685,177
CDPQ [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding		19,222,141

XML

Unaudited Condensed Consolidated Statements Of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Costs and Expenses	$ 331,684	$ 434,950	$ 1,122,731	$ 1,135,472
REVENUES	402,887	494,194	1,290,580	1,307,919
Cost of Revenue [Abstract]
Fuel Costs	96,698	188,437	411,864	392,497
Cost of Goods and Services Sold	35,748	57,386	122,410	151,891
OPERATING EXPENSES:
Utilities Operating Expense, Maintenance and Operations	120,858	116,969	356,386	367,525
Depreciation and amortization	72,021	66,810	212,292	199,096
Taxes other than income taxes	6,359	5,348	19,779	27,664
Operating Income (Loss)	71,203	59,244	167,849	172,447
Allowance for equity funds used during construction	3,134	1,408	7,089	4,782
Interest Expense	34,471	32,630	104,510	96,552
Other Nonoperating Income (Expense)	(633)	2,836	787	8,674
Nonoperating Income (Expense)	(31,970)	(28,386)	(96,634)	(83,096)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	39,233	30,858	71,215	89,351
Income Tax Expense (Benefit)	3,802	6,020	8,663	18,274
Net income	35,431	24,838	62,552	71,077
Less: dividends on preferred stock	0	803	0	2,410
Net Income (Loss) Available to Common Stockholders, Basic	35,431	24,035	62,552	68,667
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain (Loss), Net			0	(3,201)
OPERATING INCOME	71,203	59,244	167,849	172,447
OTHER (EXPENSE) / INCOME, NET:
Allowance for equity funds used during construction	3,134	1,408	7,089	4,782
Interest Expense	(34,471)	(32,630)	(104,510)	(96,552)
Other Nonoperating Income (Expense)	(633)	2,836	787	8,674
Total other expense, net	(31,970)	(28,386)	(96,634)	(83,096)
INCOME BEFORE INCOME TAX
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	39,233	30,858	71,215	89,351
Income Tax Expense (Benefit)	3,802	6,020	8,663	18,274
NET INCOME	35,431	24,838	62,552	71,077
Less: dividends on preferred stock	0	803	0	2,410
NET INCOME APPLICABLE TO COMMON STOCK	$ 35,431	$ 24,035	$ 62,552	$ 68,667

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Unaudited Condensed Consolidated Statements of Comprehensive Income Statement - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	$ (2,477)	$ (4,349)	$ (2,425)	$ (15,767)
Net Income (Loss) Available to Common Stockholders, Basic	35,431	24,035	62,552	68,667
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	7,482	13,136	7,325	47,627
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	8,840	14,494	11,398	51,700
Other Comprehensive Income (Loss), Net of Tax	8,840	14,494	11,398	51,700
Less: dividends on preferred stock	0	803	0	2,410
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	44,271	38,529	73,950	120,367
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	1,358	1,358	4,073	4,073
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	$ (449)	$ (449)	$ (1,348)	$ (1,348)

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Unaudited Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
CURRENT ASSETS:
Cash and cash equivalents	$ 21,537	$ 201,548
Restricted Cash and Cash Equivalents	5
Accounts Receivable, after Allowance for Credit Loss, Current	184,323	216,523
Accounts Receivable, Allowance for Credit Loss, Current	1,064	1,117
Inventory, Net	146,396	123,608
Regulatory assets	70,578	119,723
Income Taxes Receivable, Current	42,072	18,000
Derivative Asset	24,273	7,545
Other Assets, Current	29,610	19,882
Total current assets	518,789	706,829
UTILITY PLANT:
Property, Plant and Equipment, Gross	6,722,783	6,982,314
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	2,891,090	3,243,968
Utility plant in service - net	3,831,693	3,738,346
Construction in Progress, Gross	450,059	294,985
Total net property, plant and equipment	4,281,752	4,033,331
Other Assets, Noncurrent [Abstract]
Intangible Assets, Net (Excluding Goodwill)	220,471	138,978
Regulatory assets	567,525	593,939
Assets for Plan Benefits, Defined Benefit Plan	32,161	33,611
Derivative Asset, Noncurrent	0	12,172
Other Assets, Miscellaneous, Noncurrent	112,591	70,354
Total other non-current assets	932,748	849,054
TOTAL ASSETS	5,733,289	5,589,214
CURRENT LIABILITIES:
Debt, Current	479,273	0
Accounts payable	206,295	189,845
Accrued taxes	26,443	22,474
Interest Payable, Current	44,772	33,447
Customer deposits	36,732	35,097
Regulatory Liability, Current	53,073	23,348
Accrued Liabilities and Other Liabilities	19,471	19,014
Total current liabilities	866,059	323,225
Long-term Debt and Lease Obligation	2,616,217	3,016,810
Deferred Income Tax Liabilities, Net	359,588	312,641
NON-CURRENT LIABILITIES:
Regulatory Liability, Noncurrent	568,646	612,585
Accrued other postretirement benefits	3,027	3,085
Asset retirement obligations	216,791	218,729
Other non-current liabilities	5,366	11,621
Total non-current liabilities	3,769,635	4,175,471
Liabilities	4,635,694	4,498,696
Common shareholders' equity:
Additional Paid in Capital	1,021,968	1,068,357
Accumulated Other Comprehensive Income (Loss), Net of Tax	33,667	22,269
Accumulated deficit	41,960	(108)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,097,595	1,090,518
Total common shareholders' equity	1,097,595	1,090,518
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 5,733,289	$ 5,589,214

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Unaudited Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATIONS:
Net income	$ 62,552	$ 71,077
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	212,292	199,096
Amortization of deferred financing costs and debt discounts	2,889	2,898
Deferred income taxes and investment tax credit adjustments - net	32,735	(11,137)
Allowance for equity funds used during construction	(7,089)	(4,782)
Change in certain assets and liabilities:
Accounts receivable	32,200	(27,892)
Inventories	(30,264)	(35,826)
Accounts payable	(28,669)	25,619
Accrued and other current liabilities	2,137	4,631
Accrued taxes payable/receivable	(20,103)	1,291
Accrued interest	11,325	12,588
Pension and other postretirement benefit assets and liabilities	1,390	(6,404)
Current and non-current regulatory assets and liabilities	100,822	8,299
Prepayments and other current assets	9,728	(2,755)
Increase (Decrease) in Other Noncurrent Liabilities	(9,226)	(11,934)
Other - net	(6,176)	(3,743)
Net cash provided by operating activities	347,087	226,536
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(453,671)	(368,636)
Project development costs	(4,589)	(1,435)
Cost of removal payments, net of salvage	(36,749)	(23,075)
Other	0	(552)
Net cash used in investing activities	(534,759)	(393,698)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under revolving credit facilities	75,000	300,000
Repayments under revolving credit facilities	0	(225,000)
Short-term borrowings	0	200,000
Distributions to shareholders	66,941	101,986
Preferred dividends of subsidiary	0	(2,410)
Deferred financing costs paid	(85)	(258)
Other	(313)	(34)
Net cash provided by financing activities	7,661	170,312
Net change in cash, cash equivalents and restricted cash	(180,011)	3,150
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	21,542	10,067
Cash paid during the period for:
Interest (net of amount capitalized)	82,541	75,783
Income Taxes Paid, Net	0	31,000
Non-cash investing activities:
Capital Expenditures Incurred but Not yet Paid	106,674	53,540
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	983	(3,402)
Change in Right-of-Use Asset Lease Liability	(1,408)	(3,402)
Proceeds from Insurance Settlement, Investing Activities	$ 4,900	$ 0

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Unaudited Condensed Consolidated Statements of Common Stockholders' Equity ( Deficit) Statement - USD ($) $ in Thousands	Total	Additional Paid-in Capital [Member]	AOCI Attributable to Parent [Member]	Retained Earnings [Member]	Cumulative Preferred Stock Of Subsidiary [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 794,600	$ 848,565		$ (24,558)	$ 59,784
Other Comprehensive Income (Loss), Net of Tax	16,923		$ 16,923
Net Income (Loss) Available to Common Stockholders, Basic	46,388
Dividends, Common Stock	(35,805)
Stock Issued During Period, Value, Other	26	26
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	46,388
Preferred Stock Dividends, Income Statement Impact	803
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(803)
Payments of Ordinary Dividends, Common Stock	(35,805)
Other Comprehensive Income (Loss), Net of Tax	51,700
Net Income (Loss) Available to Common Stockholders, Basic	68,667
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	120,367
Preferred Stock Dividends, Income Statement Impact	2,410
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(2,410)
Return of Capital		(33,300)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	822,132	848,591	(12,484)	(13,975)	59,784
Net Income (Loss) Attributable to Nonredeemable Noncontrolling Interest	(1,756)
Other Comprehensive Income (Loss), Net of Tax	20,283		20,283
Net Income (Loss) Available to Common Stockholders, Basic	(1,756)
Dividends, Common Stock	(34,124)
Stock Issued During Period, Value, Other	27	27
Preferred Stock Dividends, Income Statement Impact	804
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(804)
Return of Capital		25,297
Payments of Ordinary Dividends, Common Stock	(8,827)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	806,562	823,321	7,799	(24,558)	59,784
Net Income (Loss) Attributable to Nonredeemable Noncontrolling Interest	24,035
Other Comprehensive Income (Loss), Net of Tax	14,494		14,494
Net Income (Loss) Available to Common Stockholders, Basic	24,035
Dividends, Common Stock	(32,057)
Stock Issued During Period, Value, Other	29	29
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	38,529
Preferred Stock Dividends, Income Statement Impact	803
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(803)
Return of Capital		8,022
Payments of Ordinary Dividends, Common Stock	(24,035)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	813,063	815,328	22,293	(24,558)	59,784
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,090,518	1,068,357		(108)	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	19,115
Other Comprehensive Income (Loss), Net of Tax	(7,174)		(7,174)
Net Income (Loss) Available to Common Stockholders, Basic	19,115
Dividends, Common Stock	(31,395)
Stock Issued During Period, Value, Other	31	31
Preferred Stock Dividends, Income Statement Impact	0
Return of Capital		(12,280)
Payments of Ordinary Dividends, Common Stock	(19,115)
Other Comprehensive Income (Loss), Net of Tax	11,398
Net Income (Loss) Available to Common Stockholders, Basic	62,552
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	73,950
Preferred Stock Dividends, Income Statement Impact	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	0
Return of Capital	(46,500)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,071,095	1,056,108	15,095	(108)	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	8,006
Other Comprehensive Income (Loss), Net of Tax	9,732		9,732
Net Income (Loss) Available to Common Stockholders, Basic	8,006
Dividends, Common Stock	(35,546)
Stock Issued During Period, Value, Other	16	16
Preferred Stock Dividends, Income Statement Impact	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	0
Return of Capital		34,177
Payments of Ordinary Dividends, Common Stock	(1,369)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,053,303	1,021,947	24,827	6,529	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	35,431
Other Comprehensive Income (Loss), Net of Tax	8,840		8,840
Net Income (Loss) Available to Common Stockholders, Basic	35,431
Stock Issued During Period, Value, Other	21	21
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	44,271
Preferred Stock Dividends, Income Statement Impact	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,097,595	$ 1,021,968	$ 33,667	$ 41,960	$ 0

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Overview and Summary Of Significant Accounting Policies

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

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 521,000 retail customers in the city of Indianapolis and neighboring cities, towns and communities, and adjacent rural areas all within the state of Indiana. 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 in May 2021 and 415 MW Petersburg Unit 2 in June 2023, which resulted in 630 MW of total retired economic capacity at this station. AES Indiana plans to convert the remaining two coal units at Petersburg to natural gas by the end of 2025 (for further discussion, see Note 2, "Regulatory Matters - IRP Filings and Replacement Generation - 2022 IRP" to IPALCO’s 2022 Form 10-K). The second largest station, Harding Street, uses natural gas and fuel oil to power steam and 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 peaking station that uses natural gas to power combustion turbines. As of September 30, 2023, AES Indiana’s net electric generation capacity for winter is 3,070 MW and net summer capacity is 2,925 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"). As amended in December 2022 and approved by the IURC in August 2023, the Hardy Hills Solar Project is now expected to be completed in 2024. On August 31, 2023, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 2, LLC, completed the acquisition of Petersburg Energy Center, LLC, including the development of a 250 MW solar and 180 MWh energy storage facility (the "Petersburg Energy Center Project"). As amended in October 2022 and approved by the IURC in May 2023, the Petersburg Energy Center Project is now expected to be completed in 2025.

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 nine months ended September 30, 2023 are not necessarily indicative of expected results for the year ending December 31, 2023. The accompanying condensed consolidated financial statements are unaudited and should be read in conjunction with the 2022 audited consolidated financial statements and notes thereto, which are included in IPALCO's 2022 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 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 AROs and employee benefits.

Reclassifications

Certain immaterial amounts from prior periods have been reclassified to conform to the current year presentation.

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:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	21,537	$	201,548
Restricted cash (included in Prepayments and other current assets)	5		5
Total cash, cash equivalents and restricted cash	$	21,542	$	201,553

Accounts Receivable and Allowance for Credit Losses

The following table summarizes our accounts receivable balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Accounts receivable, net
Customer receivables	$	110,746	$	125,540
Unbilled revenues	54,219		74,488
Amounts due from affiliates	3,742		239
Other	16,680		17,373
Allowance for credit losses	(1,064)		(1,117)
Total accounts receivable, net	$	184,323	$	216,523

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
$ in Thousands	2023		2022
Allowance for credit losses:
Beginning balance	$	1,117	$	647
Current period provision	5,536		4,046
Write-offs charged against allowances	(6,940)		(5,049)
Recoveries collected	1,351		1,201
Ending Balance	$	1,064	$	845

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, of our receivable balance. Amounts are written off when reasonable collections efforts have been exhausted.

Inventories

The following table summarizes our inventories balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Inventories
Fuel	$	80,162	$	60,497
Materials and supplies, net	66,234		63,111
Total inventories	$	146,396	$	123,608

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 nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
	2023		2022
	(In Thousands)
Balance as of January 1	$	218,729	$	189,509
Liabilities incurred	656		1,362
Liabilities settled	(9,946)		(20,421)
Revisions to cash flow and timing estimates	—		23,229
Accretion expense	7,352		6,169
Balance as of September 30	$	216,791	$	199,848

AES Indiana recorded adjustments to its ARO liabilities of $0.0 million and $23.2 million for the nine months ended September 30, 2023 and 2022, respectively, primarily to reflect revisions to cash flow and timing estimates due to increases to estimated ash pond closure costs and accelerated landfill closure dates. As of September 30, 2023 and December 31, 2022, 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 2022 Form 10-K.

AFUDC

In accordance with the Uniform System of Accounts prescribed by FERC, AES Indiana capitalizes an allowance for the net cost of funds (interest on borrowed funds and a reasonable rate of return on equity funds) used for construction purposes during the period of construction with a corresponding credit to income. During the three and nine months ended September 30, 2023, AFUDC equity was $3.1 million and $7.1 million, respectively, and AFUDC debt was $3.8 million and $9.5 million, respectively. During the three and nine months ended September 30, 2022, AFUDC equity was $1.4 million and $4.8 million, respectively, and AFUDC debt was $2.5 million and $5.8 million, respectively.

Intangible Assets

Finite-lived intangible assets include capitalized software and project development intangible assets amortized over their useful lives. Capitalized software of $252.3 million and $205.9 million and its corresponding accumulated amortization of $116.7 million and $107.2 million is recorded as of September 30, 2023 and December 31, 2022,

respectively. Amortization expense for capitalized software was $9.7 million and $7.6 million for the nine months ended September 30, 2023 and 2022, respectively. These capitalized software intangible assets have a 7 year-weighted average amortization period, and the estimated amortization expense is approximately $40.7 million over the next 5 years ($8.5 million in 2024, $8.4 million in 2025, $8.4 million in 2026, $7.7 million in 2027 and $7.7 million in 2028). Project development intangible assets were $84.1 million and $39.5 million as of September 30, 2023 and December 31, 2022, respectively. These project development intangible assets have a 28 year-weighted average amortization period, and the estimated amortization expense is approximately $11.6 million over the next 5 years ($1.0 million in 2024, $1.3 million in 2025, $3.1 million in 2026, $3.1 million in 2027 and $3.1 million in 2028).

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of AOCI / (AOCL) by component during the three and nine months ended September 30, 2023 and 2022 are as follows (in Thousands):

Details about AOCI / (AOCL) components	Affected line item in the Condensed Consolidated Statements of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Net losses on cash flow hedges (Note 4):	Interest expense	$	1,807	$	1,807	$	5,421	$	5,421
	Income tax effect	(449)		(449)		(1,348)		(1,348)
Total reclassifications for the period, net of income taxes		$	1,358	$	1,358	$	4,073	$	4,073

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 nine months ended September 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.

Related Party Transactions

In the second quarter of 2023, AES Indiana engaged a vendor that is a related party through a competitive RFP process as part of its replacement capacity resource construction projects. AES Indiana had payments of $29.8 million to this vendor during the nine months ended September 30, 2023.

New Accounting Pronouncements Adopted in 2023

We have assessed and determined that the new accounting pronouncements adopted did not have a material impact on the Company's Financial Statements.

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Regulatory Matters

9 Months Ended

Sep. 30, 2023

Regulated Operations [Abstract]

Regulatory Matters

2. REGULATORY MATTERS

Regulatory Rate Review

AES Indiana filed a petition with the IURC on June 28, 2023, for authority to increase its basic rates and charges to cover the rising operational costs and needs associated with continuing to serve its customers safely and reliably. The factors leading to AES Indiana's first base rate increase request in five years include inflationary impacts on operations and maintenance expenses, investments in the transmission and distribution systems, and modernization of its customer systems. AES Indiana is also seeking recovery of increased costs to support its vegetation management plan, which covers the removal of overhang and tree trimming in its service territory. The Company also seeks to better align depreciation expense with the period in which the generation plants provide service to customers and remove operational costs of the retired Petersburg units from rates. AES Indiana's proposed revenue increase is $134 million annually, or 8.9%. A hearing on this petition is expected to be held in December 2023. We expect to receive an order from the IURC and place new rates into effect by the end of the second quarter of 2024.

DSM

AES Indiana filed a petition with the IURC on May 26, 2023 asking for approval of a one year DSM interim plan. A hearing was held in September 2023, and we expect the IURC to issue an order on this proceeding during the fourth quarter of 2023.

Replacement Generation

Hardy Hills Solar Project

In December 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 1, LLC, closed on an agreement for the acquisition and construction of the 195 MW Hardy Hills Solar Project to be developed in Clinton County, Indiana. In December 2022, the agreement was amended to revise the project schedule, including shifting the completion date to 2024, and adjusting for increased project costs. On January 13, 2023, AES Indiana filed a petition with the IURC for approval of these revisions, which was approved in August 2023.

Petersburg Energy Center Project

In July 2021, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 2, LLC, executed an agreement for the acquisition and construction of a 250 MW solar and 180 MWh energy storage facility to be developed in Pike County, Indiana. In October 2022, the agreement was amended to revise the project schedule, including shifting the completion date to 2025, and adjusting for increased project costs. On December 22, 2022, AES Indiana filed a petition with the IURC for approval of these revisions, which was approved in May 2023. On August 31, 2023, AES Indiana closed on the agreement for the acquisition and construction of the Petersburg Energy Center Project. This transaction was accounted for as an asset acquisition of a variable interest entity that did not meet the definition of a business; therefore, the individual assets were recorded at their fair values. Total net assets of $48.7 million were recorded in the accompanying Consolidated Balance Sheets associated with the transaction, primarily consisting of project development intangible assets (see Note 1, "Overview and Summary of Significant Accounting Policies - Intangible Assets" for further information).

Pike County BESS Project

In June 2023, AES Indiana, through its wholly-owned subsidiary AES Indiana Devco Holdings 3, LLC, executed an agreement for the construction of the 200 MW Pike County BESS project to be developed at the AES Indiana Petersburg Plant site in Pike County, Indiana. On July 19, 2023, AES Indiana filed a petition and case-in-chief with the IURC seeking approval for a Clean Energy Project and associated timely cost recovery under Indiana Code for this project. A hearing for this case was held in October 2023, and IURC review is expected to be completed during the fourth quarter of 2023. Subject to IURC approval, the Pike County BESS project is expected to be completed in 2024.

Hoosier Wind Project

On July 5, 2023, AES Indiana filed a Notice of Intent with the IURC to request approval of a Clean Energy Project and for issuance of a CPCN for the Hoosier Wind Project acquisition. The proposed Project is the acquisition of Hoosier Wind Project, which is an existing 106 MW wind facility located in Benton County, Indiana. The Company executed the Purchase Agreement on July 28, 2023. A CPCN for this case was filed in early August 2023, and a hearing was held in October 2023. IURC review is expected to be completed during the fourth quarter of 2023.

EV Portfolio Program

On January 27, 2023, AES Indiana filed with the IURC a request to approve its EV Portfolio and associated accounting and ratemaking treatment. The EV Portfolio includes two separate parts: (1) a set of EV specific rates, tariffs, and alternative pricing structures, and (2) a set of Public Use EV Pilot Programs. The EV portfolio is designed to produce net benefits for all customers through new retail margins and grid optimization. The projected costs to successfully implement the services proposed in the EV Portfolio are estimated at $16.2 million over the three-year period. AES Indiana requested approval to defer as a regulatory asset and recover in future base rates the cost necessary to implement the EV Portfolio, including carrying charges. A hearing on this request was held in July 2023, and we expect the IURC to issue an order on this request during the fourth quarter of 2023.

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Fair Value

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUEThe 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 2022 Form 10-K.

Financial Assets and Liabilities

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 (expense) / income, 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.

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 September 30, 2023 and December 31, 2022 measured on a recurring basis and the respective category within the fair value hierarchy for IPALCO was determined as follows (In Thousands):

	Fair Value as of September 30, 2023								Fair Value as of December 31, 2022
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Financial assets:
VEBA investments:
Money market funds	$	74	$	—	$	—	$	74	$	5	$	—	$	—	$	5
Mutual funds	3,563		—		—		3,563		3,223		—		—		3,223
Total VEBA investments	3,637		—		—		3,637		3,228		—		—		3,228
FTRs	—		—		2,351		2,351		—		—		7,545		7,545
Interest rate hedges	—		21,922		—		21,922		—		12,172		—		12,172
Total financial assets measured at fair value	$	3,637	$	21,922	$	2,351	$	27,910	$	3,228	$	12,172	$	7,545	$	22,945

The following table presents a reconciliation of financial instruments, measured at fair value on a recurring basis, classified as Level 3 in the fair value hierarchy for the periods ending (In Thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Beginning Balance	$	3,294	$	14,527	$	7,545	$	1,235
Issuances	—		—		3,624		15,338
Settlements	(943)		(2,792)		(8,818)		(4,838)
Ending Balance	$	2,351	$	11,735	$	2,351	$	11,735

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:  

	September 30, 2023				December 31, 2022
	Face Value		Fair Value		Face Value		Fair Value
	(In Thousands)
Fixed-rate	$	3,033,800	$	2,730,357	$	3,033,800	$	2,775,644
Variable-rate	75,000		75,000		—		—
Total indebtedness	$	3,108,800	$	2,805,357	$	3,033,800	$	2,775,644

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

•unamortized deferred financing costs of $25.2 million and $26.3 million at September 30, 2023 and December 31, 2022, respectively; and

•unamortized discounts of $6.8 million and $7.1 million at September 30, 2023 and December 31, 2022, respectively.

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Derivative Instruments and Hedging Activities (Notes)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities [Abstract]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

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 2022 Form 10-K.

At September 30, 2023, AES Indiana's outstanding derivative instruments were as follows:

Commodity	Accounting Treatment (a)	Unit	Notional (in thousands)		Sales (in thousands)		Net Notional (in thousands)
Interest rate hedges	Designated	USD	$	400,000	$	—	$	400,000
FTRs	Not Designated	MWh	6,264		—		6,264

(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 September 30,				Interest Rate Hedges for the Nine Months Ended September 30,
$ in thousands (net of tax)	2023		2022		2023		2022
Beginning accumulated derivative gain (loss) in AOCI / (AOCL)	$	24,827	$	7,799	$	22,269	$	(29,407)
Net gains associated with current period hedging transactions	7,482		13,136		7,325		47,627
Net losses reclassified to interest expense, net of tax	1,358		1,358		4,073		4,073
Ending accumulated derivative gain in AOCI	$	33,667	$	22,293	$	33,667	$	22,293
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)	12

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 Condensed 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 net realized losses of $0.0 million and $0.2 million for the three and nine months ended September 30, 2023. There were net realized gains of $0.0 million and $1.3 million related to forward power contracts for the three and nine months ended September 30, 2022.

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 Condensed 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 September 30, 2023 and December 31, 2022, 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	September 30, 2023		December 31, 2022
FTRs	Not a Cash Flow Hedge	Derivative assets, current	$	2,351	$	7,545
Interest rate hedges	Cash Flow Hedge	Derivative assets, current	$	21,922	$	—
Interest rate hedges	Cash Flow Hedge	Derivative assets, non-current	$	—	$	12,172

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Debt

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Indebtedness

DEBT

Long-Term Debt

The following table presents our long-term debt:

		September 30,		December 31,
Series	Due	2023		2022
		(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
5.65%	December 2032	350,000		350,000
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		(6,499)		(6,651)
Deferred financing costs		(19,338)		(20,362)
Total AES Indiana first mortgage bonds		2,127,963		2,126,787
Total Long-term Debt – AES Indiana		2,127,963		2,126,787
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		(346)		(425)
Deferred financing costs		(4,896)		(5,912)
Total Long-term Debt – IPALCO Enterprises, Inc.		874,758		873,663
Total Consolidated IPALCO Long-term Debt		3,002,721		3,000,450
Less: Current Portion of Long-term Debt		404,273		—
Net Consolidated IPALCO Long-term Debt		$	2,598,448	$	3,000,450

(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.

Line of Credit

As of September 30, 2023 and December 31, 2022, AES Indiana had $75.0 million and $0.0 million in outstanding borrowings under the committed Credit Agreement, respectively.

IPALCO’s Senior Secured Notes

IPALCO has $405 million of 3.70% Senior Secured Notes due September 1, 2024 ("2024 IPALCO Notes"). Although current liquid funds are not sufficient to repay the collective amounts due under the 2024 IPALCO Notes at maturity, the Company believes it will be able to refinance the 2024 IPALCO Notes based on conversations with investment bankers, which currently indicate more than adequate demand for new IPALCO debt at its current credit ratings, and considering the Company's previous successful debt issuances.

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Income Taxes

9 Months Ended

Sep. 30, 2023

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

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 9.7% and 12.2% for the three and nine months ended September 30, 2023, respectively, as compared to 19.5% and 20.5% for the three and nine months ended September 30, 2022, 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.

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Benefit Plans

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

Benefit Plans

BENEFIT PLANS

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

	For the Three Months Ended				For the Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(In Thousands)				(In Thousands)
Components of net periodic benefit cost / (credit):
Service cost	$	1,297	$	2,238	$	3,892	$	6,714
Interest cost	7,455		4,530		22,365		13,570
Expected return on plan assets	(8,277)		(8,914)		(24,830)		(26,747)
Amortization of prior service cost	543		647		1,629		1,942
Amortization of actuarial loss	1,536		603		4,608		1,815
Net periodic benefit cost / (credit)	$	2,554	$	(896)	$	7,664	$	(2,706)

The components of net periodic benefit cost / (credit) other than service cost are included in "Other (expense) / 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 $3.2 million at September 30, 2023 and December 31, 2022, respectively, were not material to the Financial Statements in the periods covered by this report.

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Commitments And Contingencies

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments And Contingencies

COMMITMENTS AND CONTINGENCIES

Contingencies

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 September 30, 2023 and December 31, 2022, total legal loss contingencies accrued were $0.2 million and $0.1 million, respectively, which primarily related to personal injury litigation. The legal loss contingencies and settlement related accruals are included in "Accrued and other current liabilities" and "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. 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.

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.

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 CCR; 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.

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Business Segment Information (Notes)

9 Months Ended

Sep. 30, 2023

Segment Reporting Information [Line Items]

Segment Reporting Disclosure [Text Block]

BUSINESS SEGMENTS

IPALCO manages its business through one reportable operating segment, the Utility segment. The primary segment performance measure is income / (loss) before income tax as management has concluded that this measure best reflects the underlying business performance of IPALCO and is the most relevant measure considered in IPALCO's internal evaluation of the financial performance of its segment. The Utility segment is comprised of AES Indiana, a vertically integrated electric utility. with all other nonutility business activities aggregated separately. See Note 1, "Overview and Summary of Significant Accounting Policies" for further information on AES Indiana. The “Other” nonutility category primarily includes the 2024 IPALCO Notes and 2030 IPALCO Notes and related interest expense, balances 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
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	402,887	$	—	$	402,887	$	494,194	$	—	$	494,194
Depreciation and amortization	$	72,021	$	—	$	72,021	$	66,810	$	—	$	66,810
Interest expense	$	23,502	$	10,969	$	34,471	$	21,697	$	10,933	$	32,630
Income/(loss) before income tax	$	49,887	$	(10,654)	$	39,233	$	42,032	$	(11,174)	$	30,858
	Nine Months Ended						Nine Months Ended
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	1,290,580	$	—	$	1,290,580	$	1,307,919	$	—	$	1,307,919
Depreciation and amortization	$	212,292	$	—	$	212,292	$	199,096	$	—	$	199,096
Interest expense	$	71,604	$	32,906	$	104,510	$	63,703	$	32,849	$	96,552
Income/(loss) before income tax	$	104,005	$	(32,790)	$	71,215	$	122,780	$	(33,429)	$	89,351
	As of September 30, 2023						As of December 31, 2022
	Utility		Other		Total		Utility		Other		Total
Total assets	$	5,684,275	$	49,014	$	5,733,289	$	5,559,977	$	29,237	$	5,589,214

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Revenue (Notes)

9 Months Ended

Sep. 30, 2023

Revenue from External Customer [Line Items]

Revenue from Contract with Customer [Text Block]

REVENUES

Revenues are primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenues are 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. Revenues are recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities. Please see Note 13, “Revenues” to IPALCO’s 2022 Form 10-K for further discussion of our retail, wholesale and miscellaneous revenues.

AES Indiana’s revenues from contracts with customers were $393.9 million and $486.3 million for the three months ended September 30, 2023 and 2022, respectively, and $1,265.0 million and $1,285.5 million for the nine months ended September 30, 2023 and 2022, respectively. The following table presents our revenues from contracts with customers and other revenues (in thousands):

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2023		2022		2023		2022
Retail Revenues
Retail revenues from contracts with customers:
Residential	$	162,531	$	172,623	$	515,920	$	511,515
Small commercial and industrial	58,777		62,764		186,313		183,356
Large commercial and industrial	156,995		169,777		489,190		457,723
Public lighting	2,369		2,478		7,453		7,230
Other (1)	4,253		4,645		13,286		13,430
Total retail revenues from contracts with customers	384,925		412,287		1,212,162		1,173,254
Alternative revenues programs	7,877		7,457		23,153		20,381
Wholesale Revenues
Wholesale revenues from contracts with customers:	7,794		67,374		41,489		100,691
Miscellaneous Revenues
Capacity revenues	—		4,999		8,155		6,752
Transmission and other revenues	1,221		1,610		3,204		4,805
Total miscellaneous revenues from contracts with customers	1,221		6,609		11,359		11,557
Other miscellaneous revenues (2)	1,070		467		2,417		2,036
Total Revenues	$	402,887	$	494,194	$	1,290,580	$	1,307,919

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

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

The balances of receivables from contracts with customers were $167.6 million and $198.3 million as of September 30, 2023 and December 31, 2022, respectively. Payment terms for all receivables from contracts with customers typically do not extend beyond 30 days, unless a customer qualifies for payment extension.

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Leases (Notes)

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Lessor, Leases [Policy Text Block]

LEASES

Lessor

The Company is the lessor under operating leases for land, office space and operating equipment. Lease receipts from such contracts are recognized as operating lease revenues on a straight-line basis over the lease term whereas contingent rentals are recognized when earned.

The following table presents lease revenues from operating leases in which the Company is the lessor for the periods indicated (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Total lease revenues	$	455	$	274	$	1,275	$	880

The following table presents the underlying gross assets and accumulated depreciation of operating leases included in Property, plant and equipment, net for the periods indicated (in thousands):

Property, Plant and Equipment, Net	September 30, 2023		December 31, 2022
Gross assets	$	4,341	$	4,334
Less: Accumulated depreciation	(1,181)		(1,060)
Net assets	$	3,160	$	3,274

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 September 30, 2023 or December 31, 2022, respectively.

The following table shows the future lease receipts as of September 30, 2023 for the remainder of 2023 through 2027 and thereafter (in thousands):

	Operating Leases
2023	$	136
2024	544
2025	553
2026	554
2027	554
Thereafter	1,245
Total	$	3,586

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Overview and Summary Of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Receivable [Policy Text Block]

Accounts Receivable and Allowance for Credit Losses

The following table summarizes our accounts receivable balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Accounts receivable, net
Customer receivables	$	110,746	$	125,540
Unbilled revenues	54,219		74,488
Amounts due from affiliates	3,742		239
Other	16,680		17,373
Allowance for credit losses	(1,064)		(1,117)
Total accounts receivable, net	$	184,323	$	216,523

Inventory, Policy [Policy Text Block]

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
$ in Thousands	2023		2022
Allowance for credit losses:
Beginning balance	$	1,117	$	647
Current period provision	5,536		4,046
Write-offs charged against allowances	(6,940)		(5,049)
Recoveries collected	1,351		1,201
Ending Balance	$	1,064	$	845

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, of our receivable balance. Amounts are written off when reasonable collections efforts have been exhausted.

Inventories

The following table summarizes our inventories balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Inventories
Fuel	$	80,162	$	60,497
Materials and supplies, net	66,234		63,111
Total inventories	$	146,396	$	123,608

Schedule of Asset Retirement Obligations [Table Text Block]

	For the Nine Months Ended September 30,
	2023		2022
	(In Thousands)
Balance as of January 1	$	218,729	$	189,509
Liabilities incurred	656		1,362
Liabilities settled	(9,946)		(20,421)
Revisions to cash flow and timing estimates	—		23,229
Accretion expense	7,352		6,169
Balance as of September 30	$	216,791	$	199,848

Consolidation, Policy [Policy Text Block]

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.

Use Of Management Estimates

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 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 AROs and employee benefits.

Reclassifications

Certain immaterial amounts from prior periods have been reclassified to conform to the current year presentation.

Reclassifications

.

Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]

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:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	21,537	$	201,548
Restricted cash (included in Prepayments and other current assets)	5		5
Total cash, cash equivalents and restricted cash	$	21,542	$	201,553

Financing Receivable, Allowance for Credit Losses, Policy for Uncollectible Amounts [Policy Text Block]

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
$ in Thousands	2023		2022
Allowance for credit losses:
Beginning balance	$	1,117	$	647
Current period provision	5,536		4,046
Write-offs charged against allowances	(6,940)		(5,049)
Recoveries collected	1,351		1,201
Ending Balance	$	1,064	$	845

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, of our receivable balance. Amounts are written off when reasonable collections efforts have been exhausted.

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Leases, Codification Topic 842 (Policies)

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Lessor, Leases [Policy Text Block]

LEASES

Lessor

The Company is the lessor under operating leases for land, office space and operating equipment. Lease receipts from such contracts are recognized as operating lease revenues on a straight-line basis over the lease term whereas contingent rentals are recognized when earned.

The following table presents lease revenues from operating leases in which the Company is the lessor for the periods indicated (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Total lease revenues	$	455	$	274	$	1,275	$	880

The following table presents the underlying gross assets and accumulated depreciation of operating leases included in Property, plant and equipment, net for the periods indicated (in thousands):

Property, Plant and Equipment, Net	September 30, 2023		December 31, 2022
Gross assets	$	4,341	$	4,334
Less: Accumulated depreciation	(1,181)		(1,060)
Net assets	$	3,160	$	3,274

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 September 30, 2023 or December 31, 2022, respectively.

The following table shows the future lease receipts as of September 30, 2023 for the remainder of 2023 through 2027 and thereafter (in thousands):

	Operating Leases
2023	$	136
2024	544
2025	553
2026	554
2027	554
Thereafter	1,245
Total	$	3,586

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Overview and Summary Of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]

The following table summarizes our accounts receivable balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Accounts receivable, net
Customer receivables	$	110,746	$	125,540
Unbilled revenues	54,219		74,488
Amounts due from affiliates	3,742		239
Other	16,680		17,373
Allowance for credit losses	(1,064)		(1,117)
Total accounts receivable, net	$	184,323	$	216,523

Allowance for Credit Losses [Table Text Block]

The following table is a rollforward of our allowance for credit losses related to the accounts receivable balances for the nine months ended September 30, 2023 and 2022, respectively:

	For the Nine Months Ended September 30,
$ in Thousands	2023		2022
Allowance for credit losses:
Beginning balance	$	1,117	$	647
Current period provision	5,536		4,046
Write-offs charged against allowances	(6,940)		(5,049)
Recoveries collected	1,351		1,201
Ending Balance	$	1,064	$	845

Schedule of Inventory, Current [Table Text Block]

The following table summarizes our inventories balances at September 30, 2023 and December 31, 2022:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Inventories
Fuel	$	80,162	$	60,497
Materials and supplies, net	66,234		63,111
Total inventories	$	146,396	$	123,608

Schedule of Cash and Cash Equivalents [Table Text Block]

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:

	September 30,		December 31,
	2023		2022
	(In Thousands)
Cash, cash equivalents and restricted cash
Cash and cash equivalents	$	21,537	$	201,548
Restricted cash (included in Prepayments and other current assets)	5		5
Total cash, cash equivalents and restricted cash	$	21,542	$	201,553

Reclassification out of Accumulated Other Comprehensive Income

The amounts reclassified out of AOCI / (AOCL) by component during the three and nine months ended September 30, 2023 and 2022 are as follows (in Thousands):

Details about AOCI / (AOCL) components	Affected line item in the Condensed Consolidated Statements of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Net losses on cash flow hedges (Note 4):	Interest expense	$	1,807	$	1,807	$	5,421	$	5,421
	Income tax effect	(449)		(449)		(1,348)		(1,348)
Total reclassifications for the period, net of income taxes		$	1,358	$	1,358	$	4,073	$	4,073

Schedule of Asset Retirement Obligations [Table Text Block]

	For the Nine Months Ended September 30,
	2023		2022
	(In Thousands)
Balance as of January 1	$	218,729	$	189,509
Liabilities incurred	656		1,362
Liabilities settled	(9,946)		(20,421)
Revisions to cash flow and timing estimates	—		23,229
Accretion expense	7,352		6,169
Balance as of September 30	$	216,791	$	199,848

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Fair Value (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]

The fair value of assets and liabilities at September 30, 2023 and December 31, 2022 measured on a recurring basis and the respective category within the fair value hierarchy for IPALCO was determined as follows (In Thousands):

	Fair Value as of September 30, 2023								Fair Value as of December 31, 2022
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Financial assets:
VEBA investments:
Money market funds	$	74	$	—	$	—	$	74	$	5	$	—	$	—	$	5
Mutual funds	3,563		—		—		3,563		3,223		—		—		3,223
Total VEBA investments	3,637		—		—		3,637		3,228		—		—		3,228
FTRs	—		—		2,351		2,351		—		—		7,545		7,545
Interest rate hedges	—		21,922		—		21,922		—		12,172		—		12,172
Total financial assets measured at fair value	$	3,637	$	21,922	$	2,351	$	27,910	$	3,228	$	12,172	$	7,545	$	22,945

Schedule Of Face And Fair Value Of Debt

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

	September 30, 2023				December 31, 2022
	Face Value		Fair Value		Face Value		Fair Value
	(In Thousands)
Fixed-rate	$	3,033,800	$	2,730,357	$	3,033,800	$	2,775,644
Variable-rate	75,000		75,000		—		—
Total indebtedness	$	3,108,800	$	2,805,357	$	3,033,800	$	2,775,644

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities [Abstract]

Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss) [Table Text Block]

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

Schedule of Derivative Instruments [Table Text Block]

At September 30, 2023, AES Indiana's outstanding derivative instruments were as follows:

Commodity	Accounting Treatment (a)	Unit	Notional (in thousands)		Sales (in thousands)		Net Notional (in thousands)
Interest rate hedges	Designated	USD	$	400,000	$	—	$	400,000
FTRs	Not Designated	MWh	6,264		—		6,264

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

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Debt (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Schedule Long-Term Indebtedness

The following table presents our long-term debt:

		September 30,		December 31,
Series	Due	2023		2022
		(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
5.65%	December 2032	350,000		350,000
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		(6,499)		(6,651)
Deferred financing costs		(19,338)		(20,362)
Total AES Indiana first mortgage bonds		2,127,963		2,126,787
Total Long-term Debt – AES Indiana		2,127,963		2,126,787
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		(346)		(425)
Deferred financing costs		(4,896)		(5,912)
Total Long-term Debt – IPALCO Enterprises, Inc.		874,758		873,663
Total Consolidated IPALCO Long-term Debt		3,002,721		3,000,450
Less: Current Portion of Long-term Debt		404,273		—
Net Consolidated IPALCO Long-term Debt		$	2,598,448	$	3,000,450

(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.

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Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

Schedule Of Net Periodic Benefit Costs

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

	For the Three Months Ended				For the Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(In Thousands)				(In Thousands)
Components of net periodic benefit cost / (credit):
Service cost	$	1,297	$	2,238	$	3,892	$	6,714
Interest cost	7,455		4,530		22,365		13,570
Expected return on plan assets	(8,277)		(8,914)		(24,830)		(26,747)
Amortization of prior service cost	543		647		1,629		1,942
Amortization of actuarial loss	1,536		603		4,608		1,815
Net periodic benefit cost / (credit)	$	2,554	$	(896)	$	7,664	$	(2,706)

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Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2023

Segment Reporting Information [Line Items]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

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

	Three Months Ended						Three Months Ended
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	402,887	$	—	$	402,887	$	494,194	$	—	$	494,194
Depreciation and amortization	$	72,021	$	—	$	72,021	$	66,810	$	—	$	66,810
Interest expense	$	23,502	$	10,969	$	34,471	$	21,697	$	10,933	$	32,630
Income/(loss) before income tax	$	49,887	$	(10,654)	$	39,233	$	42,032	$	(11,174)	$	30,858
	Nine Months Ended						Nine Months Ended
	September 30, 2023						September 30, 2022
	Utility		Other		Total		Utility		Other		Total
Revenues	$	1,290,580	$	—	$	1,290,580	$	1,307,919	$	—	$	1,307,919
Depreciation and amortization	$	212,292	$	—	$	212,292	$	199,096	$	—	$	199,096
Interest expense	$	71,604	$	32,906	$	104,510	$	63,703	$	32,849	$	96,552
Income/(loss) before income tax	$	104,005	$	(32,790)	$	71,215	$	122,780	$	(33,429)	$	89,351
	As of September 30, 2023						As of December 31, 2022
	Utility		Other		Total		Utility		Other		Total
Total assets	$	5,684,275	$	49,014	$	5,733,289	$	5,559,977	$	29,237	$	5,589,214

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Revenue (Tables)	9 Months Ended
	Sep. 30, 2023
Disaggregation of Revenue [Line Items]
Disaggregation of Revenue [Table Text Block]

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Leases (Tables)

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Operating Lease, Lease Income [Table Text Block]

The following table shows the future lease receipts as of September 30, 2023 for the remainder of 2023 through 2027 and thereafter (in thousands):

	Operating Leases
2023	$	136
2024	544
2025	553
2026	554
2027	554
Thereafter	1,245
Total	$	3,586

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Overview and Summary of Significant Accounting Policies (Details)	3 Months Ended						9 Months Ended
	Sep. 30, 2023 USD ($) generating_station MW	Jun. 30, 2023 USD ($)	Mar. 31, 2023 USD ($)	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2023 USD ($) generating_station MW	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	May 31, 2021
Debt Instrument [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,097,595,000	$ 1,053,303,000	$ 1,071,095,000	$ 813,063,000	$ 806,562,000	$ 822,132,000	$ 1,097,595,000	$ 813,063,000	$ 1,090,518,000	$ 794,600,000
Asset Retirement Obligation, Revision of Estimate							0	23,229,000
Asset Retirement Obligation, Accretion Expense							7,352,000	6,169,000
Accumulated Other Comprehensive Income (Loss), Net of Tax	33,667,000	24,827,000			7,799,000		33,667,000		22,269,000	(29,407,000)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	7,482,000			13,136,000			7,325,000	47,627,000
Inventories	80,162,000						80,162,000		60,497,000
Cash and cash equivalents	$ 21,537,000			201,548,000			$ 21,537,000	201,548,000	201,548,000
Number of customers	521,000						521,000
Number of generating stations | generating_station	4						4
Restricted Cash and Cash Equivalents	$ 5,000			5,000			$ 5,000	5,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	21,542,000			10,067,000			21,542,000	10,067,000	201,553,000	6,917,000
Regulatory assets, current	66,234,000						66,234,000		63,111,000
Inventory, Net	146,396,000						146,396,000		123,608,000
Other Comprehensive Income (Loss), Net of Tax	8,840,000	9,732,000	(7,174,000)	14,494,000	20,283,000	$ 16,923,000	11,398,000	51,700,000
Accounts Receivable, Allowance for Credit Loss, Current	1,064,000			845,000			1,064,000	845,000	1,117,000	647,000
Accounts Receivable, Credit Loss Expense (Reversal)							5,536,000	4,046,000
Accounts Receivable, Allowance for Credit Loss, Writeoff							(6,940,000)	(5,049,000)
Accounts Receivable, Allowance for Credit Loss, Recovery							1,351,000	1,201,000
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax	33,667,000	24,827,000			$ 7,799,000		33,667,000		22,269,000	(29,407,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax				13,136,000				47,627,000
Income Tax Expense (Benefit)	3,802,000			6,020,000			8,663,000	18,274,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	35,431,000	8,006,000	19,115,000
Income Tax Expense (Benefit)	3,802,000			6,020,000			8,663,000	18,274,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	35,431,000	$ 8,006,000	$ 19,115,000
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent	$ 1,358,000			1,358,000			$ 4,073,000	4,073,000
Petersburg Unit 1 retired MW											230
Petersburg Unit 2 Planned Retirement MW in 2023							415
Preferred Resource Portfolio Coal-Fired Generation Retirement MW by 2023	630						630
Asset Retirement Obligation	$ 216,791,000			199,848,000			$ 216,791,000	199,848,000	218,729,000	$ 189,509,000
Asset Retirement Obligation, Liabilities Incurred							656,000	1,362,000
Asset Retirement Obligation, Liabilities Settled							(9,946,000)	(20,421,000)
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain (Loss), Net							0	3,201,000
Allowance for Funds Used During Construction, Capitalized Interest	3,800,000			2,500,000			9,500,000	5,800,000
Allowance for Funds Used During Construction, Equity Portion	3,100,000			1,400,000			7,100,000	4,800,000
Related Party Transaction, Purchases from Related Party							29,800,000
Capitalized Computer Software, Additions							9,700,000	7,600,000
Capitalized Computer Software, Gross	252,300,000						252,300,000		205,900,000
Development Costs, Cumulative	84,100,000			39,500,000			84,100,000	39,500,000
Capitalized Computer Software, Accumulated Amortization	$ (116,700,000)						$ (116,700,000)		$ (107,200,000)
Indianapolis Power And Light Company [Member]
Debt Instrument [Line Items]
Electric generation capability for winter, megawatts | MW	3,070						3,070
Electric generation capability for summer, megawatts | MW	2,925						2,925
Aes U.S. Investments [Member]
Debt Instrument [Line Items]
Ownership percentage by parent (percent)	82.35%						82.35%
CDPQ [Member]
Debt Instrument [Line Items]
Ownership percentage by parent (percent)	17.65%						17.65%
Ownership interest in parent company (percent)	15.00%						15.00%
AES U.S. Holdings, LLC [Member]
Debt Instrument [Line Items]
Ownership interest in parent company (percent)	85.00%						85.00%
Harding Street [Member]
Debt Instrument [Line Items]
Amount of New Operation for Battery Storage Unit, megawatts | MW	20						20
Estimated Future Amortization 2024
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Capitalized Computer Software, Amortization							$ 8,500,000
Capitalized Computer Software, Amortization							8,500,000
Estimated Future Amortization 2025
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Capitalized Computer Software, Amortization							8,400,000
Capitalized Computer Software, Amortization							8,400,000
Estimated Future Amortization 2027
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Capitalized Computer Software, Amortization							7,700,000
Capitalized Computer Software, Amortization							7,700,000
Estimated Future Amortization 2028
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Capitalized Computer Software, Amortization							7,700,000
Capitalized Computer Software, Amortization							7,700,000
5 Year Estimated Future Amortization
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of Intangible Assets							40,700,000
28 Year Weighted Average Amortization Period
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	$ 11,600,000						11,600,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	11,600,000						11,600,000
Development Costs Estimated Future Amortization 2024
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	1,000,000						1,000,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	1,000,000						1,000,000
Development Costs Estimated Future Amortization 2025
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	1,300,000						1,300,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	1,300,000						1,300,000
Development Costs Estimated Future Amortization 2026
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Development Costs Estimated Future Amortization 2027
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Development Costs Estimated Future Amortization 2028
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	3,100,000						3,100,000
Estimated Future Amortization 2026
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Capitalized Computer Software, Amortization							8,400,000
Capitalized Computer Software, Amortization							8,400,000
Interest Rate Contract [Member]
Debt Instrument [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	33,667,000			22,293,000			33,667,000	22,293,000
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Debt Instrument [Line Items]
Interest and Debt Expense	(1,807,000)			(1,807,000)			(5,421,000)	(5,421,000)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest and Debt Expense	(1,807,000)			(1,807,000)			(5,421,000)	(5,421,000)
Income Tax Expense (Benefit)	449,000			449,000			1,348,000	1,348,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	1,358,000			1,358,000			4,073,000	4,073,000
Income Tax Expense (Benefit)	449,000			449,000			1,348,000	1,348,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 1,358,000			$ 1,358,000			$ 4,073,000	$ 4,073,000

XML

Overview and Summary Of Significant Accounting Policies Schedule of Changes in Asset Retirement Obligation (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	$ 216,791	$ 199,848	$ 218,729	$ 189,509
Asset Retirement Obligation, Revision of Estimate	0	23,229
Asset Retirement Obligation, Liabilities Settled	9,946	20,421
Asset Retirement Obligation, Accretion Expense	$ 7,352	$ 6,169

XML

Overview and Summary Of Significant Accounting Policies Schedule of cash, restricted cash and cash equivalents (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	$ 21,537	$ 201,548	$ 201,548
Restricted Cash and Cash Equivalents	5		5
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 21,542	$ 201,553	$ 10,067	$ 6,917

XML

Overview and Summary Of Significant Accounting Policies Schedule of Accounts and notes receivable (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables from Customers	$ 110,746		$ 125,540
Unbilled Receivables, Current	54,219		74,488
Receivables from Stockholder	3,742		239
Other Receivables	16,680		17,373
Accounts Receivable, Allowance for Credit Loss	(1,064)		(1,117)
Accounts Receivable, after Allowance for Credit Loss, Current	184,323		216,523
Accounts Receivable, Allowance for Credit Loss, Current	1,064	$ 845	$ 1,117	$ 647
Accounts Receivable, Credit Loss Expense (Reversal)	5,536	4,046
Accounts Receivable, Allowance for Credit Loss, Writeoff	(6,940)	(5,049)
Accounts Receivable, Allowance for Credit Loss, Recovery	$ 1,351	$ 1,201

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Regulatory Matters (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	May 31, 2021
Regulatory Matters [Line Items]
Total current regulatory assets	$ 70,578	$ 119,723
Total long-term regulatory assets	567,525	593,939
Total current regulatory liabilities	53,073	23,348
Total long-term regulatory liabilities	$ 568,646	$ 612,585
Preferred Resource Portfolio Coal-Fired Generation Retirement MW by 2023	630
Petersburg Unit 1 retired MW			230
Renewable Energy Program
Regulatory Matters [Line Items]
Production Costs, Period Cost	$ 16,200
Petersburg Energy Center
Regulatory Matters [Line Items]
Finite-Lived Intangible Assets, Net	$ 48,700

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Fair Value (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Jun. 30, 2023	Dec. 31, 2022	Jun. 30, 2022	Dec. 31, 2021
Fair Value, Option, Quantitative Disclosures [Line Items]
Financial Transmission Rights Fair Value Disclosure	$ 2,351	$ 7,545	$ 2,351	$ 7,545
Forward Power Contracts Fair Value Disclosure	21,922	12,172	21,922	12,172
Investments, Fair Value Disclosure	3,637	3,228	3,637	3,228
Assets, Fair Value Disclosure	27,910	22,945	27,910	22,945
Derivative Instruments Not Designated as Hedging Instruments, Gain	0		1,300
Investments, Fair Value Disclosure	3,637	3,228	3,637	3,228
Asset Retirement Obligation, Revision of Estimate			0	23,229
Asset retirement obligations	216,791		216,791			$ 218,729
Unamortized deferred financing costs	25,200		25,200			26,300
Unamortized debt discount	6,800		6,800			7,100
Financial Transmission Rights Fair Value Disclosure	2,351	7,545	2,351	7,545
Assets, Fair Value Disclosure	27,910	22,945	27,910	22,945
Derivative Financial Instruments, Liabilities
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	2,351	11,735	2,351	11,735	$ 3,294	$ 7,545	$ 14,527	$ 1,235
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Issuances	0	0	3,624	15,338
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(943)	(2,792)	(8,818)	(4,838)
Money Market Funds [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	74	5	74	5
Investments, Fair Value Disclosure	74	5	74	5
Mutual Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	3,563	3,223	3,563	3,223
Investments, Fair Value Disclosure	3,563	3,223	3,563	3,223
Fair Value, Inputs, Level 3 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Financial Transmission Rights Fair Value Disclosure	2,351	7,545	2,351	7,545
Forward Power Contracts Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	0	0	0	0
Assets, Fair Value Disclosure	2,351	7,545	2,351	7,545
Investments, Fair Value Disclosure	0	0	0	0
Financial Transmission Rights Fair Value Disclosure	2,351	7,545	2,351	7,545
Assets, Fair Value Disclosure	2,351	7,545	2,351	7,545
Fair Value, Inputs, Level 3 [Member] | Money Market Funds [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	0	0	0	0
Fair Value, Inputs, Level 3 [Member] | Mutual Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	0	0	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Financial Transmission Rights Fair Value Disclosure	0	0	0	0
Forward Power Contracts Fair Value Disclosure	21,922	12,172	21,922	12,172
Investments, Fair Value Disclosure	0	0	0	0
Assets, Fair Value Disclosure	21,922	12,172	21,922	12,172
Investments, Fair Value Disclosure	0	0	0	0
Financial Transmission Rights Fair Value Disclosure	0	0	0	0
Assets, Fair Value Disclosure	21,922	12,172	21,922	12,172
Fair Value, Inputs, Level 2 [Member] | Money Market Funds [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	0	0	0	0
Fair Value, Inputs, Level 2 [Member] | Mutual Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	0	0	0	0
Fair Value, Inputs, Level 1 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Financial Transmission Rights Fair Value Disclosure	0	0	0	0
Forward Power Contracts Fair Value Disclosure	0	0	0	0
Investments, Fair Value Disclosure	3,637	3,228	3,637	3,228
Assets, Fair Value Disclosure	3,637	3,228	3,637	3,228
Investments, Fair Value Disclosure	3,637	3,228	3,637	3,228
Financial Transmission Rights Fair Value Disclosure	0	0	0	0
Assets, Fair Value Disclosure	3,637	3,228	3,637	3,228
Fair Value, Inputs, Level 1 [Member] | Money Market Funds [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	74	5	74	5
Investments, Fair Value Disclosure	74	5	74	5
Fair Value, Inputs, Level 1 [Member] | Mutual Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investments, Fair Value Disclosure	3,563	3,223	3,563	3,223
Investments, Fair Value Disclosure	3,563	$ 3,223	3,563	$ 3,223
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative, Notional Amount	$ 400,000		$ 400,000

XML

Fair Value Summary of fair value Assets and Liabilities Measured on a Recurring Basis (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Sep. 30, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	$ 3,637	$ 3,228
Financial Transmission Rights Fair Value Disclosure	2,351	7,545
Assets, Fair Value Disclosure	27,910	22,945
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	3,637	3,228
Financial Transmission Rights Fair Value Disclosure	0	0
Assets, Fair Value Disclosure	3,637	3,228
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	0	0
Financial Transmission Rights Fair Value Disclosure	0	0
Assets, Fair Value Disclosure	21,922	12,172
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	0	0
Financial Transmission Rights Fair Value Disclosure	2,351	7,545
Assets, Fair Value Disclosure	2,351	7,545
Money Market Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	74	5
Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	74	5
Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	0	0
Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	0	0
Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	3,563	3,223
Mutual Fund [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	3,563	3,223
Mutual Fund [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	0	0
Mutual Fund [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments, Fair Value Disclosure	$ 0	$ 0

XML

Fair Value (Schedule Of Face And Fair Value Of Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	$ 6,800	$ 7,100
Face Value	3,108,800	3,033,800
Fair Value	2,805,357	2,775,644
Fixed Rate [Member]
Debt Instrument [Line Items]
Face Value	3,033,800	3,033,800
Fair Value	2,730,357	2,775,644
Variable Rate [Member]
Debt Instrument [Line Items]
Face Value	75,000	0
Fair Value	$ 75,000	$ 0

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Derivative Instruments and Hedging Activities (Details) MWh in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2023 USD ($) MWh	Jun. 30, 2023 USD ($)	Mar. 31, 2023 USD ($)	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2023 USD ($) MWh	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Other Comprehensive Income (Loss), Net of Tax	$ 8,840,000	$ 9,732,000	$ (7,174,000)	$ 14,494,000	$ 20,283,000	$ 16,923,000	$ 11,398,000	$ 51,700,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	7,482,000			13,136,000			7,325,000	47,627,000
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	(5,375,000)						(5,375,000)
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent	1,358,000			1,358,000			4,073,000	4,073,000
Accumulated Other Comprehensive Income (Loss), Net of Tax	33,667,000	$ 24,827,000			$ 7,799,000		$ 33,667,000		$ 22,269,000	$ (29,407,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax				13,136,000				47,627,000
Maximum Length of Time Hedged in Cash Flow Hedge							12 months
Regulatory assets	70,578,000						$ 70,578,000		119,723,000
Derivative Instruments Not Designated as Hedging Instruments, Gain	0						1,300,000
Derivative Instruments Not Designated as Hedging Instruments, Loss	0						200,000
Regulatory assets	70,578,000						70,578,000		119,723,000
Derivative Instruments Not Designated as Hedging Instruments, Gain	$ 0						$ 1,300,000
FTR [Member] | Not Designated as Hedging Instrument [Member]
Purchase of Units Derivative Instruments Financial Transmission Rights | MWh	6,264						6,264
Sale of Units Derivative Instruments Financial Transmission Rights | MWh	0						0
Derivative, Nonmonetary Notional Amount, Purchase (Sales), Net | MWh	6,264						6,264
Interest Rate Swap [Member] | Designated as Hedging Instrument [Member]
Purchase of Derivative Instruments Interest Rate Swap	$ 400,000,000						$ 400,000,000
Sale of Derivative Instruments Interest Rate Swap	0						0
Derivative, Notional Amount, Purchase (Sales), Net	400,000,000						400,000,000
Interest Rate Contract [Member]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	33,667,000			$ 22,293,000			33,667,000	$ 22,293,000
Other Current Assets [Member] | FTR [Member] | Not Designated as Hedging Instrument [Member]
Derivative Asset, Fair Value, Gross Asset	2,351,000						2,351,000		7,545,000
Other Current Assets [Member] | interest rate hedge | Not Designated as Hedging Instrument [Member]
Derivative Asset, Fair Value, Gross Asset	21,922,000						21,922,000		0
Derivative Instruments and Hedges, Noncurrent	$ 0						$ 0		$ 12,172,000

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Debt (Schedule Long-Term Indebtedness) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Debt Instrument [Line Items]
Unamortized discount - net	$ (6,800)	$ (7,100)
Deferred financing costs	(25,200)	(26,300)
Long-term debt	3,002,721	3,000,450
Less: Current Portion of Long-term Debt	404,273	0
Net Consolidated IPALCO Long-term Debt	2,598,448	3,000,450
Indianapolis Power And Light Company [Member]
Debt Instrument [Line Items]
First mortgage bonds	2,127,963	2,126,787
Unamortized discount - net	(6,499)	(6,651)
Long-term debt	$ 2,127,963	2,126,787
Indianapolis Power And Light Company [Member] | First Mortgage Bond 4.55% Due December 2024 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	3.125%
First mortgage bonds	$ 40,000	40,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 6.60% Due January 2034 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	6.60%
First mortgage bonds	$ 100,000	100,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 6.05% Due October 2036 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	6.05%
First mortgage bonds	$ 158,800	158,800
Indianapolis Power And Light Company [Member] | First Mortgage Bond 6.60% Due June 2037 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	6.60%
First mortgage bonds	$ 165,000	165,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 4.875% Due November 2041 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.875%
First mortgage bonds	$ 140,000	140,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 4.65% Due June 2043 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.65%
First mortgage bonds	$ 170,000	170,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 4.50% Due June 2044[Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.50%
First mortgage bonds	$ 130,000	130,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond 4.70%, Due September 2045 [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.70%
First mortgage bonds	$ 260,000	260,000
Indianapolis Power And Light Company [Member] | FMB Twenty [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.05%
First mortgage bonds	$ 350,000	350,000
Indianapolis Power And Light Company [Member] | FMB Twenty - one [Member]
Debt Instrument [Line Items]
Debt, stated interest rate	4.875%
First mortgage bonds	$ 105,000	105,000
Indianapolis Power And Light Company [Member] | FMB Twenty - two
Debt Instrument [Line Items]
Debt, stated interest rate	0.75%
First mortgage bonds	$ 30,000	30,000
Indianapolis Power And Light Company [Member] | FMB Twenty - three
Debt Instrument [Line Items]
Debt, stated interest rate	0.95%
First mortgage bonds	$ 60,000	60,000
Indianapolis Power And Light Company [Member] | FMB Twenty - four
Debt Instrument [Line Items]
Debt, stated interest rate	1.40%
First mortgage bonds	$ 55,000	55,000
Indianapolis Power And Light Company [Member] | FMB Twenty - five
Debt Instrument [Line Items]
Debt, stated interest rate	0.65%
First mortgage bonds	$ 40,000	40,000
Indianapolis Power And Light Company [Member] | First Mortgage Bond Twenty Six
Debt Instrument [Line Items]
Debt, stated interest rate	5.65%
First mortgage bonds	$ 350,000	350,000
Ipalco Enterprises, Inc. [Member]
Debt Instrument [Line Items]
Unamortized discount - net	(346)	(425)
Deferred financing costs	(4,896)	(5,912)
Net Consolidated IPALCO Long-term Debt	$ 874,758	873,663
Ipalco Enterprises, Inc. [Member] | Three Point Seven Zero Percent Senior Secured Notes [Domain]
Debt Instrument [Line Items]
Debt, stated interest rate	3.70%
Long-term debt	$ 405,000	405,000
Ipalco Enterprises, Inc. [Member] | Four Point Two Five Percent Senior Secured Notes
Debt Instrument [Line Items]
Debt, stated interest rate	4.25%
Long-term debt	$ 475,000	475,000
First Mortgage Bonds [Member] | Indianapolis Power And Light Company [Member]
Debt Instrument [Line Items]
Deferred financing costs	(19,338)	$ (20,362)
Line of Credit [Member] | Committed Line of Credit [Member]
Debt Instrument [Line Items]
Line of credit, outstanding borrowings	$ 75,000		$ 0

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Debt (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Debt Instrument [Line Items]
Long-term Debt	$ 3,002,721	$ 3,000,450
Subsidiaries [Member]
Debt Instrument [Line Items]
Long-term Debt	2,127,963	2,126,787
Secured Debt	2,127,963	2,126,787
Subsidiaries [Member] | FMB Twenty - four
Debt Instrument [Line Items]
Secured Debt	$ 55,000	55,000
Debt Instrument, Interest Rate, Stated Percentage	1.40%
Subsidiaries [Member] | FMB Twenty - five
Debt Instrument [Line Items]
Secured Debt	$ 40,000	40,000
Debt Instrument, Interest Rate, Stated Percentage	0.65%
Parent Company [Member] | Three Point Four Five Percent Senior Secured Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 475,000	475,000
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Parent Company [Member] | Three Point Seven Zero Percent Senior Secured Notes [Domain]
Debt Instrument [Line Items]
Long-term Debt	$ 405,000	$ 405,000
Debt Instrument, Interest Rate, Stated Percentage	3.70%
Line of Credit [Member] | Committed Line of Credit [Member]
Debt Instrument [Line Items]
Line of credit, outstanding borrowings	$ 75,000		$ 0

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Income Taxes (Narrative) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
State and federal income tax rate	9.70%	19.50%	12.20%	20.50%
Effective Income Tax Rate Reconciliation, at Combined Federal and State Statutory Income Tax Rate, Percent			24.90%
Income Tax Contingency [Line Items]
State and federal income tax rate	9.70%	19.50%	12.20%	20.50%
Estimated Annual Effective Income Tax Rate			12.20%

XML

Benefit Plans (Narrative) (Details) $ in Millions	Sep. 30, 2023 USD ($)
Postretirement Health Care Benefits [Member] | Subsidiaries [Member]
Defined Benefit Plan Disclosure [Line Items]
Unfunded obligation	$ 3.2

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Benefit Plans (Schedule Of Defined Benefit Plans Disclosures) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net Unfunded Status of Plans [Roll Forward]
Service cost	$ (1,297)	$ (2,238)	$ (3,892)	$ (6,714)
Interest cost	(7,455)	(4,530)	(22,365)	(13,570)
Expected return on assets	8,277	8,914	24,830	26,747
Regulatory Assets Related to Pensions [Roll Forward]
Amortization of prior service cost	(543)	(647)	(1,629)	(1,942)
Defined Benefit Plan, Amortization of Gain (Loss)	$ (1,536)	$ (603)	$ (4,608)	$ (1,815)

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Benefit Plans (Schedule Of Net Periodic Benefit Costs) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Retirement Benefits [Abstract]
Service cost	$ 1,297	$ 2,238	$ 3,892	$ 6,714
Interest cost	7,455	4,530	22,365	13,570
Expected return on assets	(8,277)	(8,914)	(24,830)	(26,747)
Amortization of prior service cost	543	647	1,629	1,942
Amortization of actuarial loss	1,536	603	4,608	1,815
Net periodic benefit cost	$ 2,554	$ (896)	$ 7,664	$ (2,706)

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Commitments and Contingencies (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Entity Information [Line Items]
Total Legal Loss Contingencies Accrued	$ 0.2	$ 0.1

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Business Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	$ 3,802	$ 6,020	$ 8,663	$ 18,274
Net Income (Loss) Attributable to Parent	35,431	24,838	62,552	71,077
UTILITY OPERATING REVENUES	402,887	494,194	1,290,580	1,307,919
Depreciation and amortization	72,021	66,810	212,292	199,096
Interest Expense	34,471	32,630	104,510	96,552
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	39,233	30,858	71,215	89,351
Assets	5,733,289	5,589,214	5,733,289	5,589,214	$ 5,589,214
Electric [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	72,021	66,810	212,292	199,096
Interest Expense	23,502	21,697	71,604	63,703
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	49,887	42,032	104,005	122,780
Assets	5,684,275	5,559,977	5,684,275	5,559,977
Other Segments [Member]
Segment Reporting Information [Line Items]
UTILITY OPERATING REVENUES	0	0	0	0
Depreciation and amortization	0	0	0	0
Interest Expense	10,969	10,933	32,906	32,849
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	(10,654)	(11,174)	(32,790)	(33,429)
Assets	49,014	29,237	49,014	29,237
Electricity [Member]
Segment Reporting Information [Line Items]
UTILITY OPERATING REVENUES	$ 402,887	$ 494,194	$ 1,290,580	$ 1,307,919

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Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Contract with Customer, Asset, before Allowance for Credit Loss	$ 167,600		$ 167,600		$ 198,300
Revenue from Contract with Customer, Excluding Assessed Tax	393,900	$ 486,300	1,265,000	$ 1,285,500
REVENUES	402,887	494,194	1,290,580	1,307,919
Retail Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	384,925	412,287	1,212,162	1,173,254
Other non-606 revenue	7,877	7,457	23,153	20,381
Wholesale Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7,794	67,374	41,489	100,691
Miscellaneous revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,221	6,609	11,359	11,557
Other non-606 revenue	1,070	467	2,417	2,036
RTO Capacity Revenue	0		8,155	6,752
Electricity [Member]
Disaggregation of Revenue [Line Items]
REVENUES	402,887	494,194	1,290,580	1,307,919
Utility | Retail Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,253	4,645	13,286	13,430
Utility | Retail Revenue [Member] | Residential Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	162,531	172,623	515,920	511,515
Utility | Retail Revenue [Member] | Small Commercial and Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	58,777	62,764	186,313	183,356
Utility | Retail Revenue [Member] | Large Commercial and Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	156,995	169,777	489,190	457,723
Utility | Retail Revenue [Member] | Public Lighting
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,369	2,478	7,453	7,230
Transmission Revenue | Miscellaneous revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 1,221	1,610	$ 3,204	$ 4,805
RTO Capacity Revenue		$ 4,999

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Leases (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Leases [Abstract]
Operating Lease, Lease Income	$ 455	$ 274	$ 1,275	$ 880
Lessor, Operating Lease, Payment to be Received, Year One	136		136
Lessor, Operating Lease, Payment to be Received, Year Two	544		544
Lessor, Operating Lease, Payment to be Received, Year Three	553		553
Lessor, Operating Lease, Payment to be Received, Year Four	554		554
Lessor, Operating Lease, Payment to be Received, Year Five	554		554
Lessor, Operating Lease, Payment to be Received, after Year Five	1,245		1,245
Lessor, Operating Lease, Payments to be Received	3,586		3,586
Lessor, Operating Lease, Assumptions and Judgments, Value of Underlying Asset, Amount	4,341	4,334	4,341	4,334
Property Subject to or Available for Operating Lease, Accumulated Depreciation	(1,181)	(1,060)	(1,181)	(1,060)
Lessee, Lease, Description [Line Items]
Operating Lease, Lease Income	455	274	1,275	880
Lessor, Operating Lease, Assumptions and Judgments, Value of Underlying Asset, Amount	4,341	4,334	4,341	4,334
Property Subject to or Available for Operating Lease, Accumulated Depreciation	(1,181)	(1,060)	(1,181)	(1,060)
Property, Plant, and Equipment, Lessor Asset under Operating Lease, after Accumulated Depreciation	$ 3,160	$ 3,274	$ 3,160	$ 3,274