SEC Filing | CenterPoint Energy, Inc.,

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cnp-20220930

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, 2022


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

Commission file number 1-31447

CenterPoint Energy, Inc.

(Exact name of registrant as specified in its charter)


Texas			74-0694415
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1111 Louisiana	Houston	Texas	77002
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code

Commission file number 1-3187

CenterPoint Energy Houston Electric, LLC

(Exact name of registrant as specified in its charter)


Texas			22-3865106
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1111 Louisiana	Houston	Texas	77002
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code

Commission file number 1-13265

CenterPoint Energy Resources Corp.

(Exact name of registrant as specified in its charter)


Delaware			76-0511406
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1111 Louisiana	Houston	Texas	77002
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code


Securities registered pursuant to Section 12(b) of the Act:
Registrant	Title of each class	Trading Symbol(s)	Name of each exchange on which registered
CenterPoint Energy, Inc.	Common Stock, $0.01 par value	CNP	The New York Stock Exchange
			NYSE Chicago
CenterPoint Energy Houston Electric, LLC	6.95% General Mortgage Bonds due 2033	n/a	The New York Stock Exchange
CenterPoint Energy Resources Corp.	6.625% Senior Notes due 2037	n/a	The New York Stock Exchange

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.

CenterPoint Energy, Inc.

Yes

CenterPoint Energy Houston Electric, LLC

Yes

CenterPoint Energy Resources Corp.

Yes

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

CenterPoint Energy, Inc.

Yes

CenterPoint Energy Houston Electric, LLC

Yes

CenterPoint Energy Resources Corp.

Yes

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

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

CenterPoint Energy, Inc.

☐

CenterPoint Energy Houston Electric, LLC

☐

CenterPoint Energy Resources Corp.

☐

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. o

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

CenterPoint Energy, Inc.

Yes

☐

CenterPoint Energy Houston Electric, LLC

Yes

☐

CenterPoint Energy Resources Corp.

Yes

☐

Indicate the number of shares outstanding of each of the issuers’ classes of common stock as of October 24, 2022:


CenterPoint Energy, Inc.	629,535,631	shares of common stock outstanding, excluding 166 shares held as treasury stock
CenterPoint Energy Houston Electric, LLC	1,000	common shares outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.
CenterPoint Energy Resources Corp.	1,000	shares of common stock outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.

CenterPoint Energy Houston Electric, LLC and CenterPoint Energy Resources Corp. meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and are therefore filing this form with the reduced disclosure format specified in General Instruction H(2) of Form 10-Q.

TABLE OF CONTENTS


PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	CenterPoint Energy, Inc. Financial Statements (unaudited)	1




	CenterPoint Energy Houston Electric, LLC Financial Statements (unaudited)	7




	CenterPoint Energy Resources Corp. Financial Statements (unaudited)	13





	Combined Notes to Interim Condensed Financial Statements (unaudited)	19
	(1) Background and Basis of Presentation	19
	(2) New Accounting Pronouncements	20
	(3) Divestitures	20
	(4) Revenue Recognition and Allowance for Credit Losses	24
	(5) Employee Benefit Plans	27
	(6) Regulatory Matters	29
	(7) Derivative Instruments	31
	(8) Fair Value Measurements	33
	(9) Goodwill and Other Intangibles	34
	(10) Equity Securities and Indexed Debt Securities (ZENS)	36
	(11) Short-term Borrowings and Long-term Debt	37
	(12) Income Taxes	40
	(13) Commitments and Contingencies	41
	(14) Earnings Per Share	46
	(15) Reportable Segments	47
	(16) Supplemental Disclosure of Cash Flow Information	49
	(17) Related Party Transactions	50
	(18) Equity	52
	(19) Leases	54

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	57
	Recent Events	57
	Consolidated Results of Operations	58
	Results of Operations by Reportable Segment	59
	Certain Factors Affecting Future Earnings	67
	Liquidity and Capital Resources	67
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	80
Item 4.	Controls and Procedures	82

PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	82
Item 1A.	Risk Factors	82

Item 6.	Exhibits	83
	Signatures	86


GLOSSARY
ACE						Affordable Clean Energy

AFSI						Adjusted financial statement income
AFUDC						Allowance for funds used during construction

AMA						Asset Management Agreement



ARO						Asset retirement obligation

ARP						Alternative revenue program

ASC						Accounting Standards Codification
Asset Purchase Agreement						Asset Purchase Agreement, dated as of April 29, 2021, by and between CERC Corp. and Southern Col Midco

AT&T						AT&T Inc.
AT&T Common						AT&T common stock

Bcf						Billion cubic feet
Board						Board of Directors of CenterPoint Energy, Inc.
Bond Companies						Bond Company IV and Restoration Bond Company, each a wholly-owned, bankruptcy remote entity formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of Securitization Bonds
Bond Company IV						CenterPoint Energy Transition Bond Company IV, LLC, a wholly-owned subsidiary of Houston Electric
BTA						Build Transfer Agreement

Capital Dynamics						Capital Dynamics, Inc.
CARES Act						Coronavirus Aid, Relief, and Economic Security Act

CCR						Coal Combustion Residuals


CEIP						CenterPoint Energy Intrastate Pipelines, LLC, a wholly-owned subsidiary of CERC Corp.
CenterPoint Energy						CenterPoint Energy, Inc., and its subsidiaries
CERC						CERC Corp., together with its subsidiaries
CERC Corp.						CenterPoint Energy Resources Corp.
CES						CenterPoint Energy Services, Inc. (now known as Symmetry Energy Solutions, LLC), previously a wholly-owned subsidiary of CERC Corp.
Charter Common						Charter Communications, Inc. common stock
CIP						Conservation Improvement Program




CODM						Chief Operating Decision Maker, who is each Registrant’s Chief Operating Executive
Common Stock						CenterPoint Energy, Inc. common stock, par value $0.01 per share
Compensation Committee						Compensation Committee of the Board
COVID-19						Novel coronavirus disease 2019, and any mutations or variants thereof, and related global outbreak that was subsequently declared a pandemic by the World Health Organization

CPCN						Certificate of Public Convenience and Necessity
CPP						Clean Power Plan
CSIA						Compliance and System Improvement Adjustment
DCRF						Distribution Cost Recovery Factor
DOC						U.S. Department of Commerce
DRR						Distribution Replacement Rider
DSMA						Demand Side Management Adjustment


ECA						Environmental Cost Adjustment
EDIT						Excess deferred income taxes
EECR						Energy Efficiency Cost Recovery
EECRF						Energy Efficiency Cost Recovery Factor
EEFC						Energy Efficiency Funding Component
EEFR						Energy Efficiency Funding Rider


GLOSSARY
Elk GP Merger Sub						Elk GP Merger Sub LLC, a Delaware limited liability company and a direct wholly-owned subsidiary of Energy Transfer
Elk Merger Sub						Elk Merger Sub LLC, a Delaware limited liability company and a direct wholly-owned subsidiary of Energy Transfer
Enable						Enable Midstream Partners, LP
Enable Common Units						Enable common units, representing limited partner interests in Enable
Enable GP						Enable GP, LLC, Enable’s general partner
Enable Merger						The merger of Elk Merger Sub with and into Enable and the merger of Elk GP Merger Sub with and into Enable GP, in each case on the terms and subject to the conditions set forth in the Enable Merger Agreement, with Enable and Enable GP surviving as wholly-owned subsidiaries of Energy Transfer, which closed on December 2, 2021
Enable Merger Agreement						Agreement and Plan of Merger by and among Energy Transfer, Elk Merger Sub, Elk GP Merger Sub, Enable, Enable GP and, solely for the purposes of Section 2.1(a)(i) therein, Energy Transfer GP, and solely for the purposes of Section 1.1(b)(i) therein, CenterPoint Energy, Inc.
Enable Series A Preferred Units						Enable’s 10% Series A Fixed-to-Floating Non-Cumulative Redeemable Perpetual Preferred Units, representing limited partner interests in Enable
Energy Services						Offered competitive variable and fixed-priced physical natural gas supplies primarily to commercial and industrial customers and electric and natural gas utilities through CES and CEIP
Energy Services Disposal Group						Substantially all of the businesses within CenterPoint Energy’s and CERC’s Energy Services reporting unit that were sold under the Equity Purchase Agreement
Energy Systems Group						Energy Systems Group, LLC, a wholly-owned subsidiary of Vectren
Energy Transfer						Energy Transfer LP, a Delaware limited partnership
Energy Transfer Common Units						Energy Transfer common units, representing limited partner interests in Energy Transfer
Energy Transfer GP						LE GP, LLC, a Delaware limited liability company and sole general partner of Energy Transfer
Energy Transfer Series G Preferred Units						Energy Transfer Series G Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units, representing limited partner interests in Energy Transfer
EPA						Environmental Protection Agency
Equity Purchase Agreement						Equity Purchase Agreement, dated as of February 24, 2020, by and between CERC Corp. and Symmetry Energy Solutions Acquisition, LLC (f/k/a Athena Energy Services Buyer, LLC)
ERCOT						Electric Reliability Council of Texas
February 2021 Winter Storm Event						The extreme and unprecedented winter weather event in February 2021 (Winter Storm Uri) that resulted in electricity generation supply shortages, including in Texas, and natural gas supply shortages and increased wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures
FERC						Federal Energy Regulatory Commission
Fitch						Fitch Ratings, Inc.
Form 10-Q						Quarterly Report on Form 10-Q



GHG						Greenhouse gases

GRIP						Gas Reliability Infrastructure Program

GWh						Gigawatt-hours
Houston Electric						CenterPoint Energy Houston Electric, LLC and its subsidiaries
IDEM						Indiana Department of Environmental Management
Indiana Electric						Operations of SIGECO’s electric transmission and distribution services, and includes its power generating and wholesale power operations
Indiana Gas						Indiana Gas Company, Inc., formerly a wholly-owned subsidiary of Vectren, acquired by CERC on June 30, 2022
Indiana North						Gas operations of Indiana Gas
Indiana South						Gas operations of SIGECO

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GLOSSARY
Indiana Utilities						The combination of Indiana Electric, Indiana North and Indiana South


Interim Condensed Financial Statements						Unaudited condensed consolidated interim financial statements and combined notes
IRA						Inflation Reduction Act of 2022

IRP						Integrated Resource Plan
IRS						Internal Revenue Service
IURC						Indiana Utility Regulatory Commission



LIBOR						London Interbank Offered Rate
LNG						Liquefied Natural Gas
LPSC						Louisiana Public Service Commission
LTIP						Long-term Incentive Plan

Merger						The merger of Merger Sub with and into Vectren on the terms and subject to the conditions set forth in the Merger Agreement, with Vectren continuing as the surviving corporation and as a wholly-owned subsidiary of CenterPoint Energy, Inc.
Merger Agreement						Agreement and Plan of Merger, dated as of April 21, 2018, among CenterPoint Energy, Vectren and Merger Sub



MGP						Manufactured gas plant
MISO						Midcontinent Independent System Operator


Moody’s						Moody’s Investors Service, Inc.
MPSC						Mississippi Public Service Commission
MPUC						Minnesota Public Utilities Commission

MW						Megawatt
NERC						North American Electric Reliability Corporation


NOLs						Net operating losses
NOx						Oxides of nitrogen
NRG						NRG Energy, Inc.
Oriden						Oriden LLC
Origis						Origis Energy USA Inc.





OUCC						Indiana Office of Utility Consumer Counselor
Posey Solar						Posey Solar, LLC, a special purpose entity
PowerTeam Services						PowerTeam Services, LLC, a Delaware limited liability company, now known as Artera Services, LLC


PPA						Power Purchase Agreement
PRPs						Potentially responsible parties
PUCO						Public Utilities Commission of Ohio
PUCT						Public Utility Commission of Texas
Railroad Commission						Railroad Commission of Texas
RCRA						Resource Conservation and Recovery Act of 1976
Registrants						CenterPoint Energy, Houston Electric and CERC, collectively

REP						Retail electric provider
Restoration Bond Company						CenterPoint Energy Restoration Bond Company, LLC, a wholly-owned subsidiary of Houston Electric
Restructuring						CERC Corp.’s common control acquisition of Indiana Gas and VEDO from VUH on June 30, 2022

ROE						Return on equity
ROU						Right of use
RRA						Rate Regulation Adjustment
RSP						Rate Stabilization Plan
S&P						S&P Global Ratings


GLOSSARY
Scope 1 emissions						Direct source of emissions from a company’s operations
Scope 2 emissions						Indirect source of emissions from a company’s energy usage
Scope 3 emissions						Indirect source of emissions from a company’s end-users
SEC						Securities and Exchange Commission
Securities Purchase Agreement						Securities Purchase Agreement, dated as of February 3, 2020, by and among Vectren Utility Services, Inc., PowerTeam Services and, solely for purposes of Section 10.17 of the Securities Purchase Agreement, Vectren
Securitization Bonds						Transition and system restoration bonds
Series A Preferred Stock						CenterPoint Energy’s Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share
Series B Preferred Stock						CenterPoint Energy’s 7.00% Series B Mandatory Convertible Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share

Series C Preferred Stock						CenterPoint Energy’s Series C Mandatory Convertible Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share
SIGECO						Southern Indiana Gas and Electric Company, a wholly-owned subsidiary of Vectren
SOFR						Secured Overnight Financing Rate
Southern Col Midco						Southern Col Midco, LLC, a Delaware limited liability company and an affiliate of Summit Utilities, Inc.
SRC						Sales Reconciliation Component

Symmetry Energy Solutions Acquisition						Symmetry Energy Solutions Acquisition, LLC, a Delaware limited liability company (f/k/a Athena Energy Services Buyer, LLC) and subsidiary of Energy Capital Partners, LLC
TBD						To be determined

TCJA						Tax reform legislation informally called the Tax Cuts and Jobs Act of 2017
TCOS						Transmission Cost of Service
TCRF						Transmission Cost Recovery Factor
TDSIC						Transmission, Distribution and Storage System Improvement Charge
TDU						Transmission and distribution utility
TEEEF						Assets leased or costs incurred as “temporary emergency electric energy facilities” under the Public Utility Regulatory Act Section 39.918, also referred to as mobile generation


Tenaska						Tenaska Wind Holdings, LLC
Texas RE						Texas Reliability Entity



Transition Services Agreement						Transition Services Agreement by and between CenterPoint Energy Service Company, LLC and Southern Col Midco
Vectren						Vectren, LLC, which converted its corporate structure from Vectren Corporation to a limited liability company on June 30, 2022, a wholly-owned subsidiary of CenterPoint Energy as of February 1, 2019
VEDO						Vectren Energy Delivery of Ohio, LLC, which converted its corporate structure from Vectren Energy Delivery of Ohio, Inc. to a limited liability company on June 13, 2022, formerly a wholly-owned subsidiary of Vectren, acquired by CERC on June 30, 2022
VIE						Variable interest entity

Vistra Energy Corp.						Texas-based energy company focused on the competitive energy and power generation markets, whose major subsidiaries include Luminant and TXU Energy
VRP						Voluntary Remediation Program
VUH						Vectren Utility Holdings, LLC, which converted its corporate structure from Vectren Utility Holdings, Inc. to a limited liability company on June 30, 2022, a wholly-owned subsidiary of Vectren


GLOSSARY
VUH PPNs						VUH’s private senior guaranteed notes
WBD Common						Warner Bros. Discovery, Inc. Series A common stock
ZENS						2.0% Zero-Premium Exchangeable Subordinated Notes due 2029
ZENS-Related Securities						As of December 31, 2021, consisted of AT&T Common and Charter Common and, as of September 30, 2022, consisted of AT&T Common, Charter Common and WBD Common
2021 Form 10-K						Annual Report on Form 10-K for the fiscal year ended December 31, 2021 as filed with the SEC on February 22, 2022

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

From time to time the Registrants make statements concerning their expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Actual results may differ materially from those expressed or implied by these statements. You can generally identify forward-looking statements by the words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “objective,” “plan,” “potential,” “predict,” “projection,” “should,” “target,” “will” or other similar words.

The Registrants have based their forward-looking statements on management’s beliefs and assumptions based on information reasonably available to management at the time the statements are made. The Registrants caution you that assumptions, beliefs, expectations, intentions and projections about future events may and often do vary materially from actual results. Therefore, the Registrants cannot assure you that actual results will not differ materially from those expressed or implied by the Registrants’ forward-looking statements. In this Form 10-Q, unless context requires otherwise, the terms “our,” “we” and “us” are used as abbreviated references to CenterPoint Energy, Inc. together with its consolidated subsidiaries, including Houston Electric, CERC and SIGECO.

The following are some of the factors that could cause actual results to differ from those expressed or implied by the Registrants’ forward-looking statements and apply to all Registrants unless otherwise indicated:

•CenterPoint Energy’s business strategies and strategic initiatives, restructurings, joint ventures and acquisitions or dispositions of assets or businesses, including the completed sale of our Natural Gas businesses in Arkansas and Oklahoma, the exit from midstream and the Restructuring, which we cannot assure will have the anticipated benefits to us;

•industrial, commercial and residential growth in our service territories and changes in market demand, including the demand for our non-utility products and services and effects of energy efficiency measures and demographic patterns;

•our ability to fund and invest planned capital and the timely recovery of our investments, including those related to Indiana Electric’s generation transition plan as part of its most recent IRP;

•our ability to successfully construct, operate, repair and maintain electric generating facilities, natural gas facilities, TEEEF and electric transmission facilities, including complying with applicable environmental standards and the implementation of a well-balanced energy and resource mix, as appropriate;

•timely and appropriate rate actions that allow recovery of costs and a reasonable return on investment, including the timing and amount of recovered natural gas costs in some jurisdictions associated with the February 2021 Winter Storm Event and those related to Houston Electric’s TEEEF;

•future economic conditions in regional and national markets, including inflation, and their effect on sales, prices and costs;

•weather variations and other natural phenomena, including the impact of severe weather events on operations and capital, such as impacts from the February 2021 Winter Storm Event;

•increases in commodity prices;

•volatility in the markets for natural gas as a result of, among other factors, armed conflicts, including the conflict in Ukraine and the related sanctions on certain Russian entities;

•changes in rates of inflation;

•continued disruptions to the global supply chain, including tariffs and other legislation impacting the supply chain, that could prevent CenterPoint Energy from securing the resources needed to, among other things, fully execute on its 10-year capital plan or achieve its net zero and carbon emissions reduction goals;

•non-payment for our services due to financial distress of our customers and the ability of REPs to satisfy their obligations to CenterPoint Energy and Houston Electric, including the negative impact on such ability related to adverse economic conditions and severe weather events;

•the impact of pandemics, including the COVID-19 pandemic, and any associated disruptions to our businesses and our customers;

•state and federal legislative and regulatory actions or developments affecting various aspects of our businesses, including, among others, energy deregulation or re-regulation, pipeline integrity and safety and changes in regulation and legislation pertaining to trade, health care, finance and actions regarding the rates charged by our regulated businesses;

•direct or indirect effects on our facilities, resources, operations and financial condition resulting from terrorism, cyber attacks or intrusions, including as a result of global conflict such as the conflict in Ukraine, data security breaches or other attempts to disrupt our businesses or the businesses of third parties, or other catastrophic events such as fires, ice, earthquakes, explosions, leaks, floods, droughts, hurricanes, tornadoes and other severe weather events, pandemic health events or other occurrences;

vii

•the effective tax rate, including as a result of tax legislation, including the effects of the CARES Act and the IRA, as well as any changes in tax laws under the current or future administrations, and uncertainties involving state commissions’ and local municipalities’ regulatory requirements and determinations regarding the treatment of EDIT and our rates;

•our ability to mitigate weather impacts through normalization or rate mechanisms, and the effectiveness of such mechanisms;

•actions by credit rating agencies, including any potential downgrades to credit ratings;

•matters affecting regulatory approval, legislative actions, construction, implementation of necessary technology or other issues with respect to major capital projects that result in delays or cancellation or in cost overruns that cannot be recouped in rates;

•local, state and federal legislative and regulatory actions or developments relating to the environment, including, among others, those related to global climate change, air emissions, carbon, waste water discharges and the handling and disposal of CCR that could impact operations, cost recovery of generation plant costs and related assets, and CenterPoint Energy’s net zero and carbon emissions reduction goals;

•the impact of unplanned facility outages or other closures;

•the sufficiency of our insurance coverage, including availability, cost, coverage and terms and ability to recover claims;

•the availability and prices of raw materials and services and changes in labor for current and future construction projects and operations and maintenance costs, including our ability to control such costs;

•impacts from CenterPoint Energy’s pension and postretirement benefit plans, such as the investment performance and increases to net periodic costs as a result of plan settlements and changes in discount rates;

•changes in interest rates and their impact on costs of borrowing;

•commercial bank and financial market conditions, our access to capital, the cost of such capital, and the results of our financing and refinancing efforts, including availability of funds in the debt capital markets;

•inability of various counterparties to meet their obligations to us;

•the extent and effectiveness of our risk management activities;

•timely and appropriate regulatory actions, which include actions allowing securitization, for any future hurricanes or other severe weather events, or natural disasters or other recovery of costs, including stranded coal generation asset costs;

•acquisition and merger activities involving us or our industry, including the ability to successfully complete merger, acquisition and divestiture plans;

•our ability to recruit, effectively transition and retain management and key employees and maintain good labor relations;

•changes in technology, particularly with respect to efficient battery storage or the emergence or growth of new, developing or alternative sources of generation, and their adoption by consumers;

•the impact of climate change and alternate energy sources on the demand for natural gas and electricity generated or transmitted by us;

•the timing and outcome of any audits, disputes and other proceedings related to taxes;

•the recording of impairment charges;

•political and economic developments, including energy and environmental policies under the current administration;

•the transition to a replacement for the LIBOR benchmark interest rate;

•CenterPoint Energy’s ability to execute on its strategy, initiatives, targets and goals, including its net zero and carbon

emissions reduction goals and its operations and maintenance goals;

•the outcome of litigation, including litigation related to the February 2021 Winter Storm Event;

•the development of new opportunities and the performance of projects undertaken by Energy Systems Group, which are subject to, among other factors, the level of success in bidding contracts and cancellation and/or reductions in the scope of projects by customers, and obligations related to warranties, guarantees and other contractual and legal obligations;

•the effect of changes in and application of accounting standards and pronouncements; and

•other factors discussed in “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K, which are incorporated herein by reference, in Item 1A of Part II of this combined Form 10-Q, and in other reports the Registrants file from time to time with the SEC.

You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and the Registrants undertake no obligation to update or revise any forward-looking statements. Investors should note that the Registrants announce material financial and other information in SEC filings, press releases and public conference calls. Based on guidance from the SEC, the Registrants may use the Investors section of CenterPoint Energy’s website (www.centerpointenergy.com) to communicate with investors about the Registrants. It is possible that the

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financial and other information posted there could be deemed to be material information. The information on CenterPoint Energy’s website is not part of this combined Form 10-Q.

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
	(in millions, except per share amounts)
Revenues:
Utility revenues	$	1,829	$	1,661	$	6,400	$	5,797
Non-utility revenues	74		88		210		241
Total	1,903		1,749		6,610		6,038
Expenses:
Utility natural gas, fuel and purchased power	349		223		1,860		1,416
Non-utility cost of revenues, including natural gas	52		61		143		159
Operation and maintenance	670		709		2,020		2,055
Depreciation and amortization	329		353		974		987
Taxes other than income taxes	119		125		401		394

Total	1,519		1,471		5,398		5,011
Operating Income	384		278		1,212		1,027
Other Income (Expense):
Gain (loss) on equity securities	(206)		(12)		(284)		40
Gain (loss) on indexed debt securities	210		11		381		(40)
Gain on sale	—		8		303		8
Interest expense and other finance charges	(116)		(114)		(375)		(380)
Interest expense on Securitization Bonds	(3)		(5)		(11)		(16)



Other income, net	8		17		25		54
Total	(107)		(95)		39		(334)
Income from Continuing Operations Before Income Taxes	277		183		1,251		693
Income tax expense	75		33		328		63
Income from Continuing Operations	202		150		923		630
Income from Discontinued Operations (net of tax expense of $-0-, $15, $-0- and $56, respectively)	—		68		—		202
Net Income	202		218		923		832
Income allocated to preferred shareholders	13		23		37		82
Income Available to Common Shareholders	$	189	$	195	$	886	$	750

Basic earnings per common share - continuing operations	$	0.30	$	0.21	$	1.41	$	0.94
Basic earnings per common share - discontinued operations	—		0.11		—		0.35
Basic Earnings Per Common Share	0.30		0.32		1.41		1.29
Diluted earnings per common share - continuing operations	$	0.30	$	0.21	$	1.40	$	0.91
Diluted earnings per common share - discontinued operations	—		0.11		—		0.34
Diluted Earnings Per Common Share	$	0.30	$	0.32	$	1.40	$	1.25

Weighted Average Common Shares Outstanding, Basic	630		605		629		581
Weighted Average Common Shares Outstanding, Diluted	633		609		633		601

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
	(in millions)
Net Income	$	202	$	218	$	923	$	832
Other comprehensive income:
Adjustment to pension and other postretirement plans (net of tax expense (benefit) of $(9), $1, $(5) and $2)	2		4		(20)		7

Reclassification of deferred loss from cash flow hedges realized in net income (net of tax of $-0-, $-0-, $-0- and $-0-)	—		1		1		1

Other comprehensive income from unconsolidated affiliates (net of tax of $-0-, $-0-, $-0- and $-0-)	—		—		—		2
Total	2		5		(19)		10
Comprehensive income	204		223		904		842
Income allocated to preferred shareholders	13		23		37		82
Comprehensive income available to common shareholders	$	191	$	200	$	867	$	760

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions)
ASSETS
Current Assets:
Cash and cash equivalents ($110 and $92 related to VIEs, respectively)	$	114	$	230
Investment in equity securities	452		1,439

Accounts receivable ($30 and $29 related to VIEs, respectively), less allowance for credit losses of $36 and $44, respectively	773		690
Accrued unbilled revenues, less allowance for credit losses of $2 and $6, respectively	315		513

Natural gas and coal inventory	308		186
Materials and supplies	574		422
Non-trading derivative assets	29		9
Taxes receivable	—		1
Current assets held for sale	—		2,338
Regulatory assets	1,377		1,395
Prepaid expenses and other current assets ($12 and $19 related to VIEs, respectively)	141		132
Total current assets	4,083		7,355
Property, Plant and Equipment:
Property, plant and equipment	36,478		33,673
Less: accumulated depreciation and amortization	10,568		10,189
Property, plant and equipment, net	25,910		23,484
Other Assets:
Goodwill	4,294		4,294
Regulatory assets ($265 and $420 related to VIEs, respectively)	2,212		2,321

Non-trading derivative assets	6		5




Other non-current assets	214		220
Total other assets	6,726		6,840
Total Assets	$	36,719	$	37,679

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions, except par value and shares)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:
Short-term borrowings	$	514	$	7
Current portion of VIE Securitization Bonds long-term debt	153		220
Indexed debt, net	8		10
Current portion of other long-term debt	1,478		308
Indexed debt securities derivative	522		903
Accounts payable	1,028		1,196

Taxes accrued	273		378
Interest accrued	118		136
Dividends accrued	113		131
Customer deposits	109		111
Non-trading derivative liabilities	—		2


Current liabilities held for sale	—		562
Other current liabilities	295		323
Total current liabilities	4,611		4,287
Other Liabilities:
Deferred income taxes, net	3,974		3,904
Non-trading derivative liabilities	—		12
Benefit obligations	578		511
Regulatory liabilities	3,295		3,153

Other non-current liabilities	835		836
Total other liabilities	8,682		8,416
Long-term Debt:
VIE Securitization Bonds, net	240		317
Other long-term debt, net	13,195		15,241
Total long-term debt, net	13,435		15,558
Commitments and Contingencies (Note 13)
Temporary Equity (Note 18)	2		3
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized, 800,000 shares and 800,000 shares outstanding, respectively, $800 and $800 liquidation preference, respectively (Note 18)	790		790
Common stock, $0.01 par value, 1,000,000,000 shares authorized, 629,532,024 shares and 628,923,534 shares outstanding, respectively	6		6
Additional paid-in capital	8,557		8,529
Retained earnings	719		154
Accumulated other comprehensive loss	(83)		(64)
Total shareholders’ equity	9,989		9,415
Total Liabilities and Shareholders’ Equity	$	36,719	$	37,679

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Nine Months Ended September 30,
	2022		2021
	(in millions)
Cash Flows from Operating Activities:
Net income	$	923	$	832


Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	974		987

Deferred income taxes	26		86




Gain on divestitures	(303)		(8)
Loss (gain) on equity securities	284		(40)
Loss (gain) on indexed debt securities	(381)		40

Equity in earnings of unconsolidated affiliates	—		(258)
Distributions from unconsolidated affiliates	—		116
Pension contributions	(6)		(59)
Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	95		231

Inventory	(224)		(104)
Taxes receivable	1		68
Accounts payable	(119)		(53)

Net regulatory assets and liabilities	148		(2,309)
Other current assets and liabilities	(199)		(25)
Other non-current assets and liabilities	34		(95)
Other operating activities, net	72		74


Net cash provided by (used in) operating activities	1,325		(517)
Cash Flows from Investing Activities:
Capital expenditures	(3,079)		(2,148)






Proceeds from sale of marketable securities	702		—
Proceeds from divestitures	2,075		22


Other investing activities, net	73		22


Net cash used in investing activities	(229)		(2,104)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	457		(27)
Payment of obligation for finance lease	(218)		—
Proceeds from (payments of) commercial paper, net	(1,620)		596
Proceeds from long-term debt	2,089		4,493
Payments of long-term debt, including make-whole premiums	(1,519)		(2,024)




Payment of debt issuance costs	(26)		(38)


Payment of dividends on Common Stock	(328)		(278)
Payment of dividends on Preferred Stock	(48)		(106)





Other financing activities, net	(7)		(6)


Net cash provided by (used in) financing activities	(1,220)		2,610
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(124)		(11)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	254		167
Cash, Cash Equivalents and Restricted Cash at End of Period	$	130	$	156

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022			2021			2022			2021
	Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
	(in millions of dollars and shares, except authorized shares and par value amounts)
Cumulative Preferred Stock, $0.01 par value; authorized 20,000,000 shares
Balance, beginning of period	1	$	790	3	$	1,739	1	$	790	3	$	2,363


Conversion of Series B Preferred Stock and Series C Preferred Stock	—	—		(2)	(949)		—	—		(2)	(1,573)
Balance, end of period	1	790		1	790		1	790		1	790
Common Stock, $0.01 par value; authorized 1,000,000,000 shares
Balance, beginning of period	629	6		593	6		629	6		551	6
Issuances of Common Stock	—	—		36	—		—	—		77	—
Issuances related to benefit and investment plans	—	—		—	—		—	—		1	—
Balance, end of period	629	6		629	6		629	6		629	6
Additional Paid-in-Capital
Balance, beginning of period		8,544			7,553			8,529			6,914
Issuances of Common Stock, net of issuance costs		—			949			—			1,573
Issuances related to benefit and investment plans		13			15			28			30

Balance, end of period		8,557			8,517			8,557			8,517
Retained Earnings (Accumulated Deficit)
Balance, beginning of period		768			(343)			154			(845)
Net income		202			218			923			832
Common Stock dividends declared (see Note 18)		(227)			(202)			(334)			(297)
Preferred Stock dividends declared (see Note 18)		(24)			(41)			(24)			(58)





Balance, end of period		719			(368)			719			(368)
Accumulated Other Comprehensive Loss
Balance, beginning of period		(85)			(85)			(64)			(90)
Other comprehensive income (loss)		2			5			(19)			10
Balance, end of period		(83)			(80)			(83)			(80)
Total Shareholders’ Equity		$	9,989		$	8,865		$	9,989		$	8,865

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Revenues	$	935	$	874	$	2,562	$	2,344
Expenses:
Operation and maintenance	395		396		1,193		1,159
Depreciation and amortization	175		182		511		484
Taxes other than income taxes	65		64		196		192
Total	635		642		1,900		1,835
Operating Income	300		232		662		509
Other Income (Expense):
Interest expense and other finance charges	(50)		(46)		(148)		(138)
Interest expense on Securitization Bonds	(3)		(5)		(11)		(16)



Other income, net	5		4		13		12
Total	(48)		(47)		(146)		(142)
Income Before Income Taxes	252		185		516		367
Income tax expense	52		34		108		60
Net Income	$	200	$	151	$	408	$	307

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Net income	$	200	$	151	$	408	$	307




Comprehensive income	$	200	$	151	$	408	$	307

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions)
ASSETS
Current Assets:
Cash and cash equivalents ($110 and $92 related to VIEs, respectively)	$	115	$	214
Accounts receivable ($30 and $29 related to VIEs, respectively), less allowance for credit losses of $1 and $1, respectively	402		263
Accounts and notes receivable–affiliated companies	389		11
Accrued unbilled revenues	147		127
Materials and supplies	408		292



Prepaid expenses and other current assets ($12 and $19 related to VIEs, respectively)	31		49
Total current assets	1,492		956
Property, Plant and Equipment:
Property, plant and equipment	16,988		15,273
Less: accumulated depreciation and amortization	4,295		4,070
Property, plant and equipment, net	12,693		11,203
Other Assets:
Regulatory assets ($265 and $420 related to VIEs, respectively)	768		789

Other non-current assets	38		32
Total other assets	806		821
Total Assets	$	14,991	$	12,980

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions)
LIABILITIES AND MEMBER’S EQUITY
Current Liabilities:

Current portion of VIE Securitization Bonds long-term debt	$	153	$	220
Current portion of other long-term debt	200		300
Accounts payable	438		510
Accounts and notes payable–affiliated companies	39		568
Taxes accrued	159		193
Interest accrued	57		74

Other current liabilities	73		91
Total current liabilities	1,119		1,956
Other Liabilities:
Deferred income taxes, net	1,186		1,122
Benefit obligations	53		55
Regulatory liabilities	1,186		1,152

Other non-current liabilities	101		98
Total other liabilities	2,526		2,427
Long-term Debt:
VIE Securitization Bonds, net	240		317
Other long-term debt, net	6,035		4,658
Total long-term debt, net	6,275		4,975
Commitments and Contingencies (Note 13)
Member’s Equity:
Common stock	—		—
Additional paid-in capital	3,860		2,678
Retained earnings	1,211		944

Total member’s equity	5,071		3,622
Total Liabilities and Member’s Equity	$	14,991	$	12,980

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Nine Months Ended September 30,
	2022		2021
	(in millions)
Cash Flows from Operating Activities:
Net income	$	408	$	307
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	511		484
Deferred income taxes	44		8


Changes in other assets and liabilities:
Accounts and notes receivable, net	(159)		(140)
Accounts receivable/payable–affiliated companies	(35)		(31)
Inventory	(116)		(49)
Accounts payable	(11)		60

Net regulatory assets and liabilities	(40)		(190)
Other current assets and liabilities	(43)		41
Other non-current assets and liabilities	(5)		13
Other operating activities, net	(9)		(6)
Net cash provided by operating activities	545		497
Cash Flows from Investing Activities:
Capital expenditures	(1,727)		(1,108)
Increase in notes receivable–affiliated companies	(360)		—


Other investing activities, net	34		4
Net cash used in investing activities	(2,053)		(1,104)
Cash Flows from Financing Activities:


Proceeds from long-term debt	1,589		1,096
Payments of long-term debt	(444)		(540)
Increase (decrease) in notes payable–affiliated companies	(512)		32
Dividend to parent	(141)		—
Contribution from parent	1,143		—

Payment of debt issuance costs	(15)		(12)
Payment of obligation for finance lease	(218)		—

Net cash provided by financing activities	1,402		576
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(106)		(31)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	233		154
Cash, Cash Equivalents and Restricted Cash at End of Period	$	127	$	123

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022			2021			2022			2021
	Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
	(in millions, except share amounts)


Common Stock
Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—
Balance, end of period	1,000	—		1,000	—		1,000	—		1,000	—
Additional Paid-in-Capital
Balance, beginning of period		3,860			2,548			2,678			2,548
Non-cash contribution from parent		—			—			38			—
Contribution from parent		—			—			1,143			—
Other		—			—			1			—
Balance, end of period		3,860			2,548			3,860			2,548
Retained Earnings
Balance, beginning of period		1,085			719			944			563
Net income		200			151			408			307
Dividend to parent		(74)			—			(141)			—
Balance, end of period		1,211			870			1,211			870
Accumulated Other Comprehensive Loss
Balance, beginning of period		—			—			—			—

Balance, end of period		—			—			—			—
Total Member’s Equity		$	5,071		$	3,418		$	5,071		$	3,418

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
	(in millions)
Revenues:
Utility revenues	$	663	$	594	$	3,206	$	2,876
Non-utility revenues	9		15		26		49
Total	672		609		3,232		2,925
Expenses:
Utility natural gas	276		173		1,660		1,230
Non-utility cost of revenues, including natural gas	1		4		3		16
Operation and maintenance	190		223		630		709
Depreciation and amortization	113		124		333		360
Taxes other than income taxes	50		53		185		182

Total	630		577		2,811		2,497
Operating Income	42		32		421		428
Other Income (Expense):
Gain on sale	—		11		557		11
Interest expense and other finance charges	(32)		(32)		(91)		(96)


Other expense, net	—		(2)		(11)		—
Total	(32)		(23)		455		(85)
Income Before Income Taxes	10		9		876		343
Income tax expense	17		1		220		40


Net Income (Loss)	$	(7)	$	8	$	656	$	303

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
	(in millions)
Net income (loss)	$	(7)	$	8	$	656	$	303




Comprehensive income (loss)	$	(7)	$	8	$	656	$	303

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions)
ASSETS
Current Assets:
Cash and cash equivalents	$	1	$	15
Accounts receivable, less allowance for credit losses of $32 and $40, respectively	242		336
Accrued unbilled revenues, less allowance for credit losses of $1 and $6, respectively	139		335
Accounts and notes receivable–affiliated companies	30		28
Materials and supplies	104		82
Natural gas inventory	267		151
Non-trading derivative assets	23		8
Taxes receivable	21		28

Current assets held for sale	—		2,084
Regulatory assets	1,340		1,371
Prepaid expenses and other current assets	69		48
Total current assets	2,236		4,486
Property, Plant and Equipment:
Property, plant and equipment	14,075		12,934
Less: accumulated depreciation and amortization	3,985		3,826
Property, plant and equipment, net	10,090		9,108
Other Assets:
Goodwill	1,583		1,583
Regulatory assets	856		938
Non-trading derivative assets	4		4



Other non-current assets	31		34
Total other assets	2,474		2,559
Total Assets	$	14,800	$	16,153

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(Unaudited)


	September 30, 2022		December 31, 2021
	(in millions)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term borrowings	$	514	$	7
Current portion of long-term debt	1,274		—
Accounts payable	389		503
Accounts payable–affiliated companies	68		125
Notes payable–affiliated companies	—		441
Taxes accrued	112		152
Interest accrued	41		30
Customer deposits	93		92

Current liabilities held for sale	—		562
Other current liabilities	150		151
Total current liabilities	2,641		2,063
Other Liabilities:
Deferred income taxes, net	1,262		1,019


Benefit obligations	96		100
Regulatory liabilities	1,815		1,715

Other non–current liabilities	565		571
Total other liabilities	3,738		3,405
Long-Term Debt	3,297		5,552
Commitments and Contingencies (Note 13)
Stockholder’s Equity:

Additional paid-in capital	3,565		4,106
Retained earnings	1,549		1,017
Accumulated other comprehensive income	10		10
Total stockholder’s equity	5,124		5,133
Total Liabilities and Stockholder’s Equity	$	14,800	$	16,153

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Nine Months Ended September 30,
	2022		2021
	(in millions)
Cash Flows from Operating Activities:
Net income	$	656	$	303
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	333		360

Deferred income taxes	217		41

Gain on divestitures	(557)		(11)
Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	271		374
Accounts receivable/payable–affiliated companies	(59)		(4)
Inventory	(87)		(77)
Taxes receivable	—		(4)
Accounts payable	(117)		(98)



Net regulatory assets and liabilities	181		(2,153)
Other current assets and liabilities	(81)		(57)
Other non-current assets and liabilities	(5)		(42)
Other operating activities, net	1		9
Net cash provided by (used in) operating activities	753		(1,359)
Cash Flows from Investing Activities:
Capital expenditures	(1,166)		(805)
Increase in notes receivable–affiliated companies	—		(25)

Proceeds from divestiture	2,075		22
Other investing activities, net	12		(39)


Net cash provided by (used in) investing activities	921		(847)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	457		(27)

Proceeds from (payments of) commercial paper, net	(324)		338
Proceeds from long-term debt	852		1,699
Payments of long-term debt	(425)		—

Dividends to parent	(844)		—
Payment of debt issuance costs	(11)		(10)
Increase (decrease) in notes payable–affiliated companies	(1,517)		203
Contribution from parent	125		—


Other financing activities, net	(1)		(2)


Net cash provided by (used in) financing activities	(1,688)		2,201
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(14)		(5)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	15		6
Cash, Cash Equivalents and Restricted Cash at End of Period	$	1	$	1

See Combined Notes to Interim Condensed Financial Statements

Table of Contents

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022			2021			2022			2021
	Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
	(in millions, except share amounts)
Common Stock
Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—
Balance, end of period	1,000	—		1,000	—		1,000	—		1,000	—
Additional Paid-in-Capital
Balance, beginning of period		3,565			3,965			4,106			3,966
Non-cash contribution from parent		—			—			54			—
Contribution from parent		—			—			125			—
Contribution to parent for sale of Arkansas and Oklahoma Natural Gas businesses		—			—			(720)			—
Other		—			—			—			(1)
Balance, end of period		3,565			3,965			3,565			3,965
Retained Earnings
Balance, beginning of period		1,569			939			1,017			644
Net income		(7)			8			656			303
Dividend to parent		(13)			—			(124)			—
Balance, end of period		1,549			947			1,549			947
Accumulated Other Comprehensive Income
Balance, beginning of period		10			10			10			10

Balance, end of period		10			10			10			10
Total Stockholder’s Equity		$	5,124		$	4,922		$	5,124		$	4,922

See Combined Notes to Interim Condensed Financial Statements

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

COMBINED NOTES TO INTERIM CONDENSED FINANCIAL STATEMENTS

(1) Background and Basis of Presentation

General. This combined Form 10-Q is filed separately by three registrants: CenterPoint Energy, Inc., CenterPoint Energy Houston Electric, LLC and CenterPoint Energy Resources Corp. Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. Each registrant makes no representation as to information relating exclusively to the other Registrants or the subsidiaries of CenterPoint Energy other than itself or its subsidiaries.

Except as discussed in the penultimate paragraph in Note 11 to the Registrants’ Interim Condensed Financial Statements, no registrant has an obligation in respect of any other Registrant’s debt securities, and holders of such debt securities should not consider the financial resources or results of operations of any Registrant other than the obligor in making a decision with respect to such securities.

Included in this combined Form 10-Q are the Interim Condensed Financial Statements of CenterPoint Energy, Houston Electric and CERC, which are referred to collectively as the Registrants. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the Registrants’ financial statements included in the Registrants’ combined 2021 Form 10-K. The Combined Notes to Interim Condensed Financial Statements apply to all Registrants and specific references to Houston Electric and CERC herein also pertain to CenterPoint Energy, unless otherwise indicated.

Background. CenterPoint Energy, Inc. is a public utility holding company. CenterPoint Energy completed the Restructuring on June 30, 2022, whereby the equity interests in Indiana Gas and VEDO, both subsidiaries it acquired in its acquisition of Vectren on February 1, 2019, were transferred from VUH to CERC Corp. As a result, Indiana Gas and VEDO became wholly owned subsidiaries of CERC Corp., to better align CenterPoint Energy’s organizational structure with management and financial reporting and to fund future capital investments more efficiently. The Restructuring was a non-cash common control acquisition by CERC. As a result, CERC acquired these businesses at CenterPoint Energy’s historical basis in these entities and prior year amounts were recast to reflect the Restructuring as if it occurred at the earliest period presented for which CenterPoint Energy had common control. The Restructuring did not impact CenterPoint Energy’s carrying basis in any entity, its allocation of goodwill to its reporting units, or its segment presentation. Neither CenterPoint Energy nor CERC recognized any gains or losses in connection with the Restructuring. SIGECO was not acquired by CERC and remains a subsidiary of VUH. See Note 9 for a discussion of the goodwill recorded at CERC as a result of this transaction. IURC and PUCO approvals necessary for the Restructuring were received in December 2021 (IURC) and January 2022 (PUCO).

On January 10, 2022, CERC Corp. completed the sale of its Arkansas and Oklahoma Natural Gas businesses. For additional information regarding discontinued operations and divestitures, see Note 3.

As of September 30, 2022, CenterPoint Energy’s operating subsidiaries were as follows:

•Houston Electric owns and operates electric transmission and distribution facilities in the Texas gulf coast area that includes the city of Houston.

•CERC Corp. (i) directly owns and operates natural gas distribution systems in Louisiana, Minnesota, Mississippi and Texas, (ii) indirectly, through Indiana Gas and VEDO, owns and operates natural gas distribution systems in Indiana and Ohio, respectively, and (iii) owns and operates permanent pipeline connections through interconnects with various interstate and intrastate pipeline companies through CEIP.

•SIGECO provides energy delivery services to electric and natural gas customers located in and near Evansville in southwestern Indiana and owns and operates electric generation assets to serve its electric customers and optimizes those assets in the wholesale power market; and

•Energy Systems Group provides energy performance contracting and sustainable infrastructure services, such as renewables, distributed generation and combined heat and power projects.

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As of September 30, 2022, CenterPoint Energy’s reportable segments were Electric and Natural Gas. Houston Electric and CERC each consist of a single reportable segment. For a description of CenterPoint Energy’s reportable segments, see Note 15.

As of September 30, 2022, CenterPoint Energy and Houston Electric had VIEs consisting of the Bond Companies, which are consolidated. The consolidated VIEs are wholly-owned, bankruptcy-remote, special purpose entities that were formed solely for the purpose of securitizing transition and system restoration-related property. Creditors of CenterPoint Energy and Houston Electric have no recourse to any assets or revenues of the Bond Companies. The bonds issued by these VIEs are payable only from and secured by transition and system restoration property, and the bondholders have no recourse to the general credit of CenterPoint Energy or Houston Electric.

Basis of Presentation. The preparation of the Registrants’ financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

The Interim Condensed Financial Statements reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position, results of operations and cash flows for the respective periods. Amounts reported in the Condensed Statements of Consolidated Income are not necessarily indicative of amounts expected for a full-year period due to the effects of, among other things, (a) seasonal fluctuations in demand for energy, (b) changes in energy commodity prices, (c) timing of maintenance and other expenditures and (d) acquisitions and dispositions of businesses, assets and other interests.

Certain prior year amounts have been reclassified to conform to the current year reportable segment presentation described in Note 15 and to reflect the impacts of discontinued operations and the Restructuring.

(2) New Accounting Pronouncements

The following table provides an overview of certain recently adopted accounting pronouncements applicable to all the Registrants.

Recently Adopted Accounting Standards

ASU Number and Name

Description

Date of Adoption

Financial Statement Impact
upon Adoption

ASU 2021-10: Government Assistance (Topic 832)

Disclosures by Business Entities about Government

Assistance

This standard requires additional disclosure requirements when a business receives government assistance and uses a grant or contribution accounting model by analogy to other accounting guidance such as the grant model under International Accounting Standards (IAS) 20 Accounting for Government Grants and Disclosures of Government Assistance and GAAP ASC 958-605 Not for Profit.

Transition method: Prospective or retrospective

January 1, 2022

Adoption of this standard may result in additional disclosures related to the recovery of Texas natural gas costs associated with the February 2021 Winter Storm Event through the state securitization, which is expected to be accounted for as a government grant by analogy to IAS 20. The adoption of this standard did not have a material impact on the Registrants’ financial position, results of operations or cash flows.

Management believes that other recently adopted standards and recently issued standards that are not yet effective will not have a material impact on the Registrants’ financial position, results of operations or cash flows upon adoption.

(3) Divestitures (CenterPoint Energy and CERC)

Divestiture of Arkansas and Oklahoma Natural Gas Businesses. On April 29, 2021, CenterPoint Energy, through its subsidiary CERC Corp., entered into an Asset Purchase Agreement to sell its Arkansas and Oklahoma Natural Gas businesses for $2.15 billion in cash, including recovery of approximately $425 million in natural gas costs, including storm-related incremental natural gas costs associated with the February 2021 Winter Storm Event, subject to certain adjustments set forth in the Asset Purchase Agreement. The assets include approximately 17,000 miles of main pipeline in Arkansas, Oklahoma and certain portions of Bowie County, Texas serving more than half a million customers. The transaction closed on January 10, 2022.

The sale was considered an asset sale for tax purposes, requiring net deferred tax liabilities to be excluded from held for sale balances. The deferred taxes associated with the businesses were recognized as a deferred income tax benefit by CenterPoint Energy and CERC upon closing of the sale in 2022.

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Although the Arkansas and Oklahoma Natural Gas businesses met the held for sale criteria as of December 31, 2021, their disposals did not represent a strategic shift to CenterPoint Energy and CERC, as both retained significant operations in, and continued to invest in, their natural gas businesses. Therefore, the income and expenses associated with the disposed businesses were not reflected as discontinued operations on CenterPoint Energy’s and CERC’s Condensed Statements of Consolidated Income, as applicable. Since the depreciation on the Arkansas and Oklahoma Natural Gas assets continued to be reflected in revenues through customer rates until the closing of the transaction and will be reflected in the carryover basis of the rate-regulated assets, CenterPoint Energy and CERC continued to record depreciation on those assets through the closing of the transaction. The Registrants record assets and liabilities held for sale at the lower of their carrying value or their estimated fair value less cost to sell.

CenterPoint Energy and CERC recognized gains of $303 million and $557 million, respectively, net of transaction costs of $59 million, in connection with the closing of the disposition of the Arkansas and Oklahoma Natural Gas businesses during the nine months ended September 30, 2022. CenterPoint Energy and CERC collected a receivable of $15 million in May 2022 for full and final settlement of the working capital adjustment under the Asset Purchase Agreement.

As a result of the completion of the sale of the Arkansas and Oklahoma Natural Gas businesses, there were no assets or liabilities classified as held for sale as of September 30, 2022. The assets and liabilities of the Arkansas and Oklahoma Natural Gas businesses classified as held for sale in CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets, as applicable, as of December 31, 2021 included the following:


	December 31, 2021
	CenterPoint Energy		CERC
	(in millions)
Receivables, net	$	46	$	46
Accrued unbilled revenues	48		48
Natural gas inventory	46		46
Materials and supplies	9		9
Property, plant and equipment, net	1,314		1,314
Goodwill (1)	398		144
Regulatory assets	471		471
Other	6		6
Total current assets held for sale	$	2,338	$	2,084

Short term borrowings (2)	$	36	$	36
Accounts payable	40		40
Taxes accrued	7		7

Customer deposits	12		12
Regulatory liabilities	365		365
Other	102		102
Total current liabilities held for sale	$	562	$	562

(1)See Note 9 for further information about the allocation of goodwill to the disposed businesses.

(2)Represents third-party AMAs associated with utility distribution service in Arkansas and Oklahoma. These transactions are accounted for as an inventory financing. For further information, see Note 11.

The pre-tax income for the Arkansas and Oklahoma Natural Gas businesses, excluding interest and corporate allocations, included in CenterPoint Energy’s and CERC’s Condensed Statements of Consolidated Income is as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022 (1)		2021		2022 (1)		2021
	(in millions)
Income from Continuing Operations Before Income Taxes	$	—	$	(14)	$	9	$	48

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(1)Reflects January 1, 2022 to January 9, 2022 results only due to of the sale of the Arkansas and Oklahoma Natural Gas businesses.

Effective on the date of the closing of the disposition of the Arkansas and Oklahoma Natural Gas businesses, a subsidiary of CenterPoint Energy entered into the Transition Services Agreement, whereby that subsidiary agreed to provide certain transition services such as accounting, customer operations, procurement, and technology functions for a term of up to twelve months. Subject to the conditions in the Transition Services Agreement, Southern Col Midco may terminate these support services with 60 days prior written notice. In September 2022, Southern Col Midco provided notice of their intent to terminate a significant majority of all services under the Transition Services Agreement, with such termination expected to occur in November 2022.

CenterPoint Energy’s charges to Southern Col Midco for reimbursement of transition services were $10 million and $29 million during the three and nine months ended September 30, 2022. Actual transitional services costs incurred are recorded net of amounts charged to Southern Col Midco. CenterPoint Energy had accounts receivable from Southern Col Midco of $7 million as of September 30, 2022 for transition services.

Discontinued Operations (CenterPoint Energy)

Enable Merger. On December 2, 2021, Enable, completed the previously announced Enable Merger pursuant to the Enable Merger Agreement entered into on February 16, 2021. At the closing of the Enable Merger on December 2, 2021, Energy Transfer acquired 100% of Enable’s outstanding common and preferred units, resulting in the exchange of Enable Common Units owned by CenterPoint Energy for Energy Transfer Common Units and the exchange of Enable Series A Preferred Units owned by CenterPoint Energy for Energy Transfer Series G Preferred Units.

During the nine months ended September 30, 2022, CenterPoint Energy sold all of its remaining Energy Transfer Common Units and Energy Transfer Series G Preferred Units. See Note 10 for further information regarding Energy Transfer equity securities.

Additionally, CenterPoint Energy’s disposal of its interests in Enable represented a strategic shift that will have a major effect on CenterPoint Energy’s operations or financial results, and as such, its equity investment in Enable was classified and presented as held for sale. The equity in earnings of unconsolidated affiliates, net of tax, associated with CenterPoint Energy’s equity investment in Enable was reflected as discontinued operations on CenterPoint Energy’s Condensed Statements of Consolidated Income for the three and nine months ended September 30, 2021.

A summary of discontinued operations presented in CenterPoint Energy’s Condensed Statements of Consolidated Income is as follows:


	Equity Method Investment in Enable
	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021

	(in millions)
Equity in earnings of unconsolidated affiliate, net	$	83	$	258
Income from discontinued operations before income taxes	83		258
Income tax expense	15		56
Net income from discontinued operations	$	68	$	202

CenterPoint Energy has elected not to separately disclose discontinued operations on its respective Condensed Statements of Consolidated Cash Flows. The following table summarizes CenterPoint Energy’s cash flows from discontinued operations and certain supplemental cash flow disclosures, as applicable:


	Equity Method Investment in Enable
	Nine Months Ended September 30, 2021
	(in millions)
Equity in earnings of unconsolidated affiliate - operating	$	(258)
Distributions from unconsolidated affiliate - operating	116

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Distributions Received from Enable (CenterPoint Energy):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021				2021
	Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable Common Units	$	0.16525	$	39	$	0.49575	$	116
Enable Series A Preferred Units	0.54390		8		1.75620		26
Total CenterPoint Energy			$	47			$	142

Transactions with Enable (CenterPoint Energy and CERC):


	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021
	(in millions)
Natural gas expenses, includes transportation and storage costs	$	14	$	62

Summarized Financial Information for Enable (CenterPoint Energy)

As a result of the closing of the Enable Merger in 2021, there were no assets classified as held for sale as of December 31, 2021. Summarized consolidated balance sheet information for Enable on the closing of the Enable Merger is as follows:


	December 2, 2021
	(in millions)
Current assets	$	594
Non-current assets	11,227
Current liabilities	1,254
Non-current liabilities	3,281
Non-controlling interest	26
Preferred equity	362
Accumulated other comprehensive loss	(1)
Enable partners’ equity	6,899

Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,701
CenterPoint Energy’s basis difference	(2,732)

CenterPoint Energy’s equity method investment in Enable	$	969

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Summarized unaudited consolidated income information for Enable is as follows:


	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021
	(in millions)
Operating revenues	$	956	$	2,713
Cost of sales, excluding depreciation and amortization	565		1,510
Depreciation and amortization	104		313

Operating income	152		482
Net income attributable to Enable Common Units	107		341


Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	58	$	183
Basis difference amortization (1)	25		75


CenterPoint Energy’s equity in earnings, net (2)	$	83	$	258

(1)Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s share of Enable earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s investment in Enable and its underlying equity in net assets of Enable. The basis difference was being amortized through the year 2048 and ceased upon closing of the Enable Merger.

(2)Reported as discontinued operations on CenterPoint Energy’s Condensed Statements of Consolidated Income.

(4) Revenue Recognition and Allowance for Credit Losses

Revenues from Contracts with Customers

In accordance with ASC 606, Revenue from Contracts with Customers, revenue is recognized when a customer obtains control of promised goods or services. The amount of revenue recognized reflects the consideration to which the Registrants expect to be entitled to receive in exchange for these goods or services.

ARPs are contracts between the utility and its regulators, not between the utility and a customer. The Registrants recognize ARP revenue as other revenues when the regulator-specified conditions for recognition have been met. Upon recovery of ARP revenue through incorporation in rates charged for utility service to customers, ARP revenue is reversed and recorded as revenue from contracts with customers. The recognition of ARP revenues and the reversal of ARP revenues upon recovery through rates charged for utility service may not occur in the same period.

The following tables disaggregate revenues by reportable segment and major source:

CenterPoint Energy


	Three Months Ended September 30, 2022
	Electric		Natural Gas		Corporate and Other		Total
	(in millions)
Revenue from contracts	$	1,155	$	686	$	65	$	1,906

Other (1)	(9)		6		—		(3)

Total revenues	$	1,146	$	692	$	65	$	1,903

	Nine Months Ended September 30, 2022
	Electric		Natural Gas		Corporate and Other		Total
	(in millions)
Revenue from contracts	$	3,113	$	3,358	$	182	$	6,653
Other (1)	(21)		(24)		2		(43)

Total revenues	$	3,092	$	3,334	$	184	$	6,610

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	Three Months Ended September 30, 2021
	Electric		Natural Gas		Corporate and Other		Total
	(in millions)
Revenue from contracts	$	1,056	$	611	$	73	$	1,740
Other (1)	—		8		1		9

Total revenues	$	1,056	$	619	$	74	$	1,749

	Nine Months Ended September 30, 2021
	Electric		Natural Gas		Corporate and Other		Total
	(in millions)
Revenue from contracts	$	2,822	$	2,984	$	190	$	5,996
Other (1)	1		38		3		42

Total revenues	$	2,823	$	3,022	$	193	$	6,038

(1)Primarily consists of income from ARPs and leases. Total lease income was $1 million and $2 million for the three months ended September 30, 2022 and 2021, respectively, and $5 million and $6 million for the nine months ended September 30, 2022 and 2021, respectively.

Houston Electric


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Revenue from contracts	$	949	$	880	$	2,597	$	2,358
Other (1)	(14)		(6)		(35)		(14)
Total revenues	$	935	$	874	$	2,562	$	2,344

(1)Primarily consists of income from ARPs and leases. Lease income was not significant for the three and nine months ended September 30, 2022 and 2021.

CERC


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Revenue from contracts	$	667	$	602	$	3,257	$	2,893
Other (1)	5		7		(25)		32

Total revenues	$	672	$	609	$	3,232	$	2,925

(1)Primarily consists of income from ARPs and leases. Lease income was not significant for the three and nine months ended September 30, 2022 and 2021.

Revenues from Contracts with Customers

Electric (CenterPoint Energy and Houston Electric). Houston Electric transmits and distributes electricity to customers over time, and customers consume the electricity when delivered. Indiana Electric generates, transmits and distributes electricity to customers over time, and customers consume the electricity when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by state regulators, such as the PUCT and the IURC, is recognized as electricity is delivered and represents amounts both billed and unbilled. Discretionary services requested by customers are provided at a point in time with control transferring upon the completion of the service. Revenue for discretionary services provided by Houston Electric is recognized upon completion of service based on the tariff rates set by the PUCT. Payments for electricity distribution and discretionary services are aggregated and received on a monthly basis. Houston Electric performs transmission services over time as a stand-ready obligation to provide a reliable network of transmission systems. Revenue is recognized upon time elapsed, and the monthly tariff rate set by the regulator. Payments are received on a monthly basis. Indiana Electric customers are billed monthly and payment terms, set by the regulator, require payment within a month of billing.

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Natural Gas (CenterPoint Energy and CERC). CenterPoint Energy and CERC distribute and transport natural gas to customers over time, and customers consume the natural gas when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by the state governing agency for that service area, is recognized as natural gas is delivered and represents amounts both billed and unbilled. Discretionary services requested by the customer are satisfied at a point in time and revenue is recognized upon completion of service and the tariff rates set by the applicable state regulator. Payments of natural gas distribution, transportation and discretionary services are aggregated and received on a monthly basis.

Contract Balances. When the timing of delivery of service is different from the timing of the payments made by customers and when the right to consideration is conditioned on something other than the passage of time, the Registrants recognize either a contract asset (performance precedes billing) or a contract liability (customer payment precedes performance). Those customers that prepay are represented by contract liabilities until the performance obligations are satisfied. The Registrants’ contract assets are included in Accrued unbilled revenues in their Condensed Consolidated Balance Sheets. As of September 30, 2022, CenterPoint Energy’s contract assets primarily relate to Energy Systems Group contracts where revenue is recognized using the input method. The Registrants’ contract liabilities are included in Accounts payable and Other current liabilities in their Condensed Consolidated Balance Sheets. As of September 30, 2022, CenterPoint Energy’s contract liabilities primarily relate to Energy Systems Group contracts where revenue is recognized using the input method.

The opening and closing balances of accounts receivable related to ASC 606 revenues, other accrued unbilled revenue, contract assets and contract liabilities from contracts with customers, excluding balances related to assets held for sale, as of December 31, 2021 and September 30, 2022, respectively, are presented below.

CenterPoint Energy


	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Assets		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2021	$	627	$	513	$	15	$	16
Closing balance as of September 30, 2022	741		315		2		51
Increase (decrease)	$	114	$	(198)	$	(13)	$	35

The amount of revenue recognized during the nine-month period ended September 30, 2022 that was included in the opening contract liability was $15 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between CenterPoint Energy’s performance and the customer’s payment.

Houston Electric


	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2021	$	225	$	127	$	4
Closing balance as of September 30, 2022	371		147		4
Increase (decrease)	$	146	$	20	$	—

The amount of revenue recognized during the nine-month period ended September 30, 2022 that was included in the opening contract liability was $3 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between Houston Electric’s performance and the customer’s payment.

CERC


	Accounts Receivable		Other Accrued Unbilled Revenues
	(in millions)
Opening balance as of December 31, 2021	$	319	$	335
Closing balance as of September 30, 2022	261		139
Increase (decrease)	$	(58)	$	(196)

CERC does not have any opening or closing contract asset or contract liability balances.

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Remaining Performance Obligations (CenterPoint Energy). The table below discloses (1) the aggregate amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of the end of the reporting period for contracts and (2) when CenterPoint Energy expects to recognize this revenue. Such contracts include energy performance and sustainable infrastructure services contracts of Energy Systems Group, which are included in Corporate and Other.


	Rolling 12 Months		Thereafter		Total
	(in millions)
Revenue expected to be recognized on contracts in place as of September 30, 2022:

Corporate and Other	$	310	$	574	$	884
	$	310	$	574	$	884

Practical Expedients and Exemption. Sales taxes and other similar taxes collected from customers are excluded from the transaction price. For contracts for which revenue from the satisfaction of the performance obligations is recognized in the amount invoiced, the practical expedient was elected and revenue expected to be recognized on these contracts has not been disclosed.

Allowance for Credit Losses

CenterPoint Energy and CERC segregate financial assets that fall under the scope of Topic 326, primarily trade receivables due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, among others. Houston Electric recognizes losses on financial assets that fall under the scope of Topic 326. Losses on financial assets are primarily recoverable through regulatory mechanisms and do not materially impact Houston Electric's allowance for credit losses. For a discussion of regulatory deferrals related to the February 2021 Winter Storm Event, see Note 6.

(5) Employee Benefit Plans

The Registrants’ net periodic cost, before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes, includes the following components relating to pension and postretirement benefits:

Pension Benefits (CenterPoint Energy)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Service cost (1)	$	7	$	9	$	23	$	29
Interest cost (2)	20		15		52		44
Expected return on plan assets (2)	(21)		(26)		(69)		(78)

Amortization of net loss (2)	8		9		22		28
Settlement cost (benefit) (2) (3)	8		27		38		26

Net periodic cost	$	22	$	34	$	66	$	49

(1)Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Energy’s Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.

(2)Amounts presented in the table above are included in Other income, net in CenterPoint Energy’s Condensed Statements of Consolidated Income, net of regulatory deferrals.

(3)Amounts presented represent a one-time, non-cash settlement cost (benefit), prior to regulatory deferrals, which are required when the total lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of the net periodic cost for that year.

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Postretirement Benefits


	Three Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Service cost (1)	$	—	$	—	$	1	$	1	$	—	$	—
Interest cost (2)	3		1		1		2		1		1
Expected return on plan assets (2)	(1)		(1)		(1)		(1)		(1)		—
Amortization of prior service credit (2)	(1)		(1)		—		(1)		(1)		—
Amortization of net loss (2)	(1)		(1)		—		—		—		—




Net periodic cost (benefit)	$	—	$	(2)	$	1	$	1	$	(1)	$	1

	Nine Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Service cost (1)	$	1	$	—	$	1	$	2	$	—	$	1
Interest cost (2)	7		3		3		6		3		2
Expected return on plan assets (2)	(3)		(3)		(1)		(3)		(3)		—
Amortization of prior service cost (credit) (2)	(2)		(3)		1		(3)		(3)		—
Amortization of net loss (2)	(3)		(2)		(1)		—		—		—




Net periodic cost (benefit)	$	—	$	(5)	$	3	$	2	$	(3)	$	3

(1)Amounts presented in the tables above are included in Operation and maintenance expense in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.

(2)Amounts presented in the tables above are included in Other income (expense), net in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of regulatory deferrals.

The table below reflects the expected minimum contributions to be made to the pension and postretirement benefit plans during 2022:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2022	$	7	$	—	$	—
Expected minimum contribution to postretirement benefit plans in 2022	8		1		4

The table below reflects the contributions made to the pension and postretirement benefit plans:


	Three Months Ended September 30, 2022						Nine Months Ended September 30, 2022
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	2	$	—	$	—	$	6	$	—	$	—
Postretirement benefit plans	2		—		1		6		1		3

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(6) Regulatory Matters

Equity Return

The Registrants are at times allowed by a regulator to defer an equity return as part of the recoverable carrying costs of a regulatory asset. A deferred equity return is capitalized for rate-making purposes, but it is not included in the Registrant’s regulatory assets on its Condensed Consolidated Balance Sheets. The allowed equity return is recognized in the Condensed Statements of Consolidated Income as it is recovered in rates. The recoverable allowed equity return not yet recognized by the Registrants is as follows:


	September 30, 2022						December 31, 2021
	CenterPoint Energy (1)		Houston Electric (2)		CERC (3)		CenterPoint Energy (1)		Houston Electric (2)		CERC (3)
	(in millions)
Allowed equity return not recognized	$	185	$	83	$	52	$	199	$	100	$	51

(1)In addition to the amounts described in (2) and (3) below, represents CenterPoint Energy’s allowed equity return on post in-service carrying cost generally associated with investments at SIGECO.

(2)Represents Houston Electric’s allowed equity return on its true-up balance of stranded costs, other changes and related interest resulting from the formerly integrated electric utilities prior to Texas deregulation to be recovered in rates through 2024 and certain storm restoration and TEEEF balances pending recovery in the next rate proceeding. The actual amounts recognized are adjusted at least annually to correct any over-collections or under-collections during the preceding 12 months.

(3)CERC’s allowed equity return on post in-service carrying cost associated with certain distribution facilities replacements expenditures in Texas and costs associated with investments in Indiana.

The table below reflects the amount of allowed equity return recognized by each Registrant in its Condensed Statements of Consolidated Income:


	Three Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Allowed equity return recognized	$	14	$	12	$	1	$	12	$	11	$	—

	Nine Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Allowed equity return recognized	$	36	$	33	$	2	$	31	$	29	$	1

February 2021 Winter Storm Event

Amounts for the under recovery of natural gas costs associated with the February 2021 Winter Storm Event are reflected in current and non-current regulatory assets on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets. Recovery of natural gas costs within the regulatory assets as of September 30, 2022 are probable and may be subject to customary regulatory prudence reviews in all jurisdictions that may impact the amounts ultimately recovered. CenterPoint Energy and CERC have begun recovery of natural gas costs in Louisiana, Mississippi and Minnesota, and recovery of natural gas costs in Indiana is complete. CenterPoint Energy and CERC have filed for securitization of natural gas costs in Texas, received commission approval and issuance of financing order in 2022, and expect the Texas Public Financing Authority to issue customer rate relief bonds in 2022. As part of the closing of the sale of CenterPoint Energy’s and CERC’s Natural Gas businesses in Arkansas and Oklahoma, CERC received as part of the purchase price $398 million for unrecovered natural gas costs associated with the February 2021 Winter Storm Event. In Minnesota, testimonies were filed in CERC’s high gas cost prudency review case by intervenors proposing significant disallowances for all natural gas utilities and for CERC, ranging

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from $45 million to $409 million. The natural gas costs in Minnesota were incurred in accordance with the plan on file with the MPUC and CenterPoint Energy believes the costs were prudently incurred and are eligible for recovery. In May 2022, the administrative law judges reviewing the gas prudency case concluded that CERC acted prudently in connection with the February 2021 Winter Storm Event and recommended no disallowance of CERC’s jurisdictional gas costs incurred during the event. The commissioners of the MPUC heard oral arguments on the administrative law judges’ report and held deliberations in August 2022. At the deliberations, the MPUC generally found that CERC acted prudently, but it determined that CERC could have done more to offset costs with natural gas storage, peak shaving resources (LNG and propane-air) and curtailment of service to interruptible commercial/industrial customers. As a result, the MPUC disallowed recovery of approximately $36 million of the $409 million originally requested and CERC’s regulatory asset balance as of September 30, 2022 was reduced to reflect the disallowance. Other natural gas utilities in Minnesota received disallowances related to similar topics in a similar proportion to their gas costs. Further, the MPUC required all regulated natural gas utilities to make a filing explaining how they can improve or modify their practices to protect ratepayers from extraordinary natural gas price spikes in the future. CERC made its compliance filing on September 15, 2022. On October 19, 2022, the MPUC issued its written order. CERC is reviewing the final order and any motion for reconsideration is due by November 8, 2022.

As of September 30, 2022, both CenterPoint Energy and CERC have recorded current regulatory assets of $1,175 million and non-current regulatory assets of $225 million associated with the February 2021 Winter Storm Event. As of December 31, 2021, CenterPoint Energy and CERC have recorded current regulatory assets of $1,410 million and $1,399 million, respectively, of which $154 million related to Arkansas and Oklahoma has been reflected in held for sale at both CenterPoint Energy and CERC, and non-current regulatory assets of $583 million and $583 million, respectively, of which $244 million related to Arkansas and Oklahoma has been reflected in held for sale at both CenterPoint Energy and CERC, associated with the February 2021 Winter Storm Event.

As of both September 30, 2022 and December 31, 2021, as authorized by the PUCT, CenterPoint Energy and Houston Electric recorded a regulatory asset of $8 million for bad debt expenses resulting from REPs’ default on their obligation to pay delivery charges to Houston Electric net of collateral. Additionally, both CenterPoint Energy and Houston Electric recorded a regulatory asset of $16 million and $15 million as of September 30, 2022 and December 31, 2021, respectively, to defer operations and maintenance costs associated with the February 2021 Winter Storm Event.

See Note 13(d) for further information regarding litigation related to the February 2021 Winter Storm Event.

Houston Electric TEEEF

Houston Electric continues to review the effects of legislation passed in 2021 and is working with the PUCT regarding proposed rulemakings and pursuing implementation of these items where applicable. For example, pursuant to legislation passed in 2021, Houston Electric entered into two leases for TEEEF (mobile generation) which are detailed in Note 19. Houston Electric is seeking to recover the lease costs for the TEEEF and the operational costs for transportation, mobilization and demobilization, labor and materials for interconnections, fuel for commissioning, testing and operation, purchase and lease of auxiliary equipment, and labor and materials for operations in its latest DCRF application. Houston Electric filed its DCRF application with the PUCT on April 5, 2022, and subsequently amended such filing on July 1, 2022 to show mobile generation in a separate Rider TEEEF, seeking recovery of deferred costs and the applicable return as of December 31, 2021 under these lease agreements of approximately $200 million. The annual revenue increase requested for these lease agreements is approximately $57 million. Intervenors in the proceeding filed testimony on September 16, 2022 challenging the acquisition and deployment of TEEEF and have recommended disallowances based on the overall contractual obligations. Houston Electric’s rebuttal testimony was filed on October 5, 2022 responding to intervenor positions, including estimating a financial loss impact ranging from $335 million to $354 million if the PUCT disallows recovery of TEEEF costs and the termination clause under the long-term lease is exercised. The termination clause in the long-term lease agreement contains certain provisions that allow Houston Electric to terminate the lease within a specific window effective between October 1, 2022, and March 31, 2023 based upon a material adverse regulatory action. Houston Electric’s exposure to loss in the event of a full disallowance of TEEEF related investments and assuming Houston Electric is unable to exercise the termination clause prior to its expiration, could be in excess of $805 million, which includes the total payments under the short-term and long-term lease agreements, allowed return and other related costs. On October 13, 2022, the PUCT staff filed a statement of position recommending a longer amortization period for the short-term lease, deferral of associated rate case expenses to the next base rate proceeding and exclusion of the retail transmission rate class from allocation of TEEEF costs. Houston Electric indicated to the PUCT staff that it did not oppose their recommendations. The PUCT staff also reserved the right to take positions on additional issues after consideration of the evidence admitted into the record at the hearing. A hearing was held on October 18 through 20, 2022. Briefs are due November 16, 2022 and reply briefs are due December 2, 2022. The administrative law judges are expected to issue a proposal for decision in late January 2023, which will ultimately be decided by the PUCT issuance of a final order expected in March or April of 2023.

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Houston Electric defers costs associated with the short-term and long-term leases that are probable of recovery and would otherwise be charged to expense in a regulatory asset, including allowed returns, and determined that such regulatory assets remain probable of recovery as of September 30, 2022. Right of use finance lease assets, such as assets acquired under the long-term leases, are evaluated for impairment under the long-lived asset impairment model by assessing if a capital disallowance from a regulator is probable through monitoring the outcome of rate cases and other proceedings. Houston Electric continues to monitor the on-going proceedings and did not record any impairments on its right of use assets in the three or nine months ended September 30, 2022. See Note 19 for further information.

(7) Derivative Instruments

The Registrants are exposed to various market risks. These risks arise from transactions entered into in the normal course of business. The Registrants utilize derivative instruments such as swaps and options to mitigate the impact of changes in commodity prices, weather and interest rates on operating results and cash flows.

(a)Non-Trading Activities

Commodity Derivative Instruments (CenterPoint Energy and CERC). CenterPoint Energy and CERC, through the Indiana Utilities, enter into certain derivative instruments to mitigate the effects of commodity price movements. Outstanding derivative instruments designated as economic hedges at the Indiana Utilities hedge long-term variable rate natural gas purchases. The Indiana Utilities have authority to refund and recover mark-to-market gains and losses associated with hedging natural gas purchases, and thus the gains and losses on derivatives are deferred in a regulatory liability or asset.

Interest Rate Risk Derivative Instruments. From time to time, the Registrants may enter into interest rate derivatives that are designated as economic or cash flow hedges. The objective of these hedges is to offset risk associated with interest rates borne by the Registrants in connection with an anticipated future fixed rate debt offering or other exposure to variable rate debt. The Indiana Utilities have authority to refund and recover mark-to-market gains and losses associated with hedging financing activity, and thus the gains and losses on derivatives are deferred in a regulatory liability or asset.

The table below summarizes CenterPoint Energy’s outstanding interest rate hedging activity:


	September 30, 2022		December 31, 2021
Hedging Classification	Notional Principal

	(in millions)
Economic hedge (1)	$	84	$	84

(1)Relates to interest rate derivative instruments at SIGECO. On June 13, 2022, SIGECO amended the LIBOR interest rate swaps to adjust the termination date to May 1, 2023.

Weather Normalization (CenterPoint Energy and CERC). CenterPoint Energy and CERC have weather normalization or other rate mechanisms that largely mitigate the impact of weather on Natural Gas in Indiana, Louisiana, Mississippi, Minnesota and Ohio, as applicable. CenterPoint Energy’s and CERC’s Natural Gas in Texas and CenterPoint Energy’s electric operations in Texas and Indiana do not have such mechanisms, although fixed customer charges are historically higher in Texas for Natural Gas compared to its other jurisdictions. As a result, fluctuations from normal weather may have a positive or negative effect on CenterPoint Energy’s and CERC’s Natural Gas’ results in Texas and on CenterPoint Energy’s electric operations’ results in its Texas and Indiana service territories. The Registrants do not currently enter into weather hedges.

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(b)Derivative Fair Values and Income Statement Impacts (CenterPoint Energy and CERC)

The following tables present information about derivative instruments and hedging activities. The first table provides a balance sheet overview of derivative assets and liabilities, while the last table provides a breakdown of the related income statement impacts.

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy


		September 30, 2022				December 31, 2021
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value




Derivatives not designated as hedging instruments:		(in millions)
Natural gas derivatives (1)	Current Assets: Non-trading derivative assets	$	28	$	—	$	9	$	—
Natural gas derivatives (1)	Other Assets: Non-trading derivative assets	6		—		5		—

Interest rate derivatives	Current Assets: Non-trading derivative assets	1		—		—		—
Interest rate derivatives	Current Liabilities: Non-trading derivative liabilities	—		—		—		2

Interest rate derivatives	Other Liabilities: Non-trading derivative liabilities	—		—		—		12
Indexed debt securities derivative (2)	Current Liabilities	—		522		—		903

Total		$	35	$	522	$	14	$	917

CERC


		September 30, 2022				December 31, 2021
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value




Derivatives not designated as hedging instruments:		(in millions)
Natural gas derivatives (1)	Current Assets: Non-trading derivative assets	$	23	$	—	$	8	$	—
Natural gas derivatives (1)	Other Assets: Non-trading derivative assets	4		—		4		—






Total		$	27	$	—	$	12	$	—

(1)Natural gas contracts are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due. However, the mark-to-market fair value of each natural gas contract is in an asset position with no offsetting amounts.

(2)Derivative component of the ZENS obligation that represents the ZENS holder’s option to receive the appreciated value of the reference shares at maturity. See Note 10 for further information.

Income Statement Impact of Hedge Accounting Activity (CenterPoint Energy)


		Three Months Ended September 30,				Nine Months Ended September 30,
	Income Statement Location	2022		2021		2022		2021
Derivatives not designated as hedging instruments:		(in millions)
Indexed debt securities derivative (1)	Gain (loss) on indexed debt securities	$	210	$	11	$	381	$	(40)

(1)The indexed debt securities derivative is recorded at fair value and changes in the fair value are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Certain of CenterPoint Energy’s derivative instruments contain provisions that require CenterPoint Energy’s debt to maintain an investment grade credit rating on its long-term unsecured unsubordinated debt from S&P and Moody’s. If

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CenterPoint Energy’s debt were to fall below investment grade, it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment.


	September 30, 2022 (1)		December 31, 2021
	(in millions)
Aggregate fair value of derivatives with credit risk-related contingent features in a liability position	$	—	$	14
Fair value of collateral already posted	—		7
Additional collateral required to be posted if credit risk contingent features triggered (2)	—		7

(1)As of September 30, 2022, all derivatives with credit risk-related contingent features were in an asset position.

(2)The maximum collateral required if further escalating collateral is triggered would equal the net liability position.

(8) Fair Value Measurements

Assets and liabilities that are recorded at fair value in the Registrants’ Condensed Consolidated Balance Sheets are categorized based upon the level of judgment associated with the inputs used to measure their value. Hierarchical levels, as defined below and directly related to the amount of subjectivity associated with the inputs to fair valuations of these assets and liabilities, are as follows:

Level 1: Inputs are unadjusted quoted prices in active markets for identical assets or liabilities at the measurement date. The types of assets carried at Level 1 fair value generally are exchange-traded derivatives and equity securities.

Level 2: Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means. Fair value assets and liabilities that are generally included in this category are derivatives with fair values based on inputs from actively quoted markets. A market approach is utilized to value the Registrants’ Level 2 natural gas derivative assets or liabilities. CenterPoint Energy’s Level 2 indexed debt securities derivative is valued using an option model and a discounted cash flow model, which uses projected dividends on the ZENS-Related Securities and a discount rate as observable inputs.

Level 3: Inputs are unobservable for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. Unobservable inputs reflect the Registrants’ judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Registrants develop these inputs based on the best information available, including the Registrants’ own data.

The Registrants determine the appropriate level for each financial asset and liability on a quarterly basis.

The following tables present information about the Registrants’ assets and liabilities measured at fair value on a recurring basis as of September 30, 2022 and December 31, 2021 and indicate the fair value hierarchy of the valuation techniques utilized by the Registrants to determine such fair value.

CenterPoint Energy


	September 30, 2022						December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(in millions)
Equity securities	$	452	$	—	$	—	$	452	$	1,439	$	—	$	—	$	1,439
Investments, including money market funds (1)	32		—		—		32		42		—		—		42
Interest rate derivatives	—		1		—		1		—		—		—		—
Natural gas derivatives	—		34		—		34		—		14		—		14



Total assets	$	484	$	35	$	—	$	519	$	1,481	$	14	$	—	$	1,495
Liabilities
Indexed debt securities derivative	$	—	$	522	$	—	$	522	$	—	$	903	$	—	$	903
Interest rate derivatives	—		—		—		—		—		14		—		14




Total liabilities	$	—	$	522	$	—	$	522	$	—	$	917	$	—	$	917

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Houston Electric


	September 30, 2022						December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(in millions)
Investments, including money market funds (1)	$	17	$	—	$	—	$	17	$	27	$	—	$	—	$	27

Total assets	$	17	$	—	$	—	$	17	$	27	$	—	$	—	$	27

CERC


	September 30, 2022						December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	(in millions)

Investments, including money market funds (1)	$	13	$	—	$	—	$	13	$	14	$	—	$	—	$	14
Natural gas derivatives	—		27		—		27		—		12		—		12
Total assets	$	13	$	27	$	—	$	40	$	14	$	12	$	—	$	26

(1)Amounts are included in Prepaid expenses and other current assets in the Condensed Consolidated Balance Sheets.

Estimated Fair Value of Financial Instruments

The fair values of cash and cash equivalents, investments in debt and equity securities measured at fair value and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. The carrying amounts of non-trading derivative assets and liabilities and CenterPoint Energy’s ZENS indexed debt securities derivative are stated at fair value and are excluded from the table below. The fair value of each debt instrument is determined by multiplying the principal amount of each debt instrument by a combination of historical trading prices and comparable issue data. These liabilities, which are not measured at fair value in the Registrants’ Condensed Consolidated Balance Sheets, but for which the fair value is disclosed, would be classified as Level 2 in the fair value hierarchy.


	September 30, 2022						December 31, 2021
	CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	(in millions)


Carrying amount	$	15,066	$	6,628	$	4,571	$	16,086	$	5,495	$	5,552
Fair value	13,482		5,649		4,324		17,385		6,230		5,999

(1)Includes Securitization Bond debt.

(9) Goodwill and Other Intangibles (CenterPoint Energy and CERC)

Goodwill (CenterPoint Energy and CERC)

CenterPoint Energy’s goodwill by reportable segment as of both September 30, 2022 and December 31, 2021 is as follows:



	(in millions)
Electric (1)	$	936
Natural Gas (2)	2,920
Corporate and Other	438

Total	$	4,294

CERC’s goodwill has been recast to reflect the Restructuring and as of both September 30, 2022 and December 31, 2021 is as follows:



	(in millions)
Goodwill (2) (3)	$	1,583

(1)Amount presented is net of the accumulated goodwill impairment charge of $185 million recorded in 2020.

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(2)Excludes $398 million and $144 million, respectively, of goodwill attributable to the Arkansas and Oklahoma Natural Gas businesses which was reflected on CenterPoint Energy’s and CERC’s respective Condensed Consolidated Balance Sheets in Current assets held for sale as of December 31, 2021 and disposed following the completion of the sale in January 2022. For further information, see Note 3.

(3)Includes $972 million of goodwill attributable to the businesses transferred in the Restructuring. See below for a discussion of the goodwill valuation determination.

When the net assets or equity interest transferred in a common-control transaction constitute a business, goodwill is included with the net assets transferred at the parent company’s historical basis. CenterPoint Energy applied a relative fair value methodology to determine the amount of goodwill to allocate to CERC from its natural gas reporting unit as part of the Restructuring.

When a disposal group reflects a component of a reporting unit and meets the definition of a business, the goodwill within that reporting unit is allocated to the disposal group based on the relative fair value of the components representing a business that will be retained and disposed. Goodwill attributable to the disposed Natural Gas businesses was classified as held for sale as of December 31, 2021 and excluded from the table above.

CenterPoint Energy and CERC perform goodwill impairment tests at least annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. The impairment evaluation for goodwill is performed by comparing the fair value of each reporting unit with the carrying amount of the reporting unit, including goodwill. The reporting units approximate the reportable segments, with the exception of Energy Systems Group, which is a separate reporting unit but included in the Corporate and Other reconciling category at CenterPoint Energy. The estimated fair value of the reporting unit is primarily determined based on an income approach or a weighted combination of income and market approaches. If the carrying amount is in excess of the estimated fair value of the reporting unit, then the excess amount is recorded as an impairment charge, not to exceed the carrying amount of goodwill.

CenterPoint Energy and CERC performed their annual goodwill impairment tests in the third quarter of 2022 and determined that no goodwill impairment charge was required for any reporting unit as a result of those tests.

Other Intangibles (CenterPoint Energy)

The tables below present information on CenterPoint Energy’s intangible assets, excluding goodwill, recorded in Other non-current assets on CenterPoint Energy’s Condensed Consolidated Balance Sheets and the related amortization expense included in Depreciation and amortization on CenterPoint Energy’s Condensed Statements of Consolidated Income.


	September 30, 2022						December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Net Balance		Gross Carrying Amount		Accumulated Amortization		Net Balance
	(in millions)
Customer relationships	$	33	$	(15)	$	18	$	33	$	(12)	$	21

Trade names	16		(6)		10		16		(5)		11

Operation and maintenance agreements (1)	12		(1)		11		12		(1)		11
Other	2		(1)		1		2		(1)		1
Total	$	63	$	(23)	$	40	$	63	$	(19)	$	44

(1)Amortization expense related to the operation and maintenance agreements is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Condensed Statements of Consolidated Income.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	1	$	1	$	4	$	4

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CenterPoint Energy estimates that amortization expense of intangible assets with finite lives for the next five years will be as follows:


	Amortization Expense

	(in millions)
Remaining three months of 2022	$	2
2023	6
2024	5
2025	5
2026	5
2027	4

(10) Equity Securities and Indexed Debt Securities (ZENS) (CenterPoint Energy)

(a) Equity Securities

During February and March 2022, CenterPoint Energy executed its previously announced plan to exit the midstream sector by selling the remaining Energy Transfer Common Units and Energy Transfer Series G Preferred Units it held as discussed below. CenterPoint Energy used the proceeds from these sales to redeem outstanding debt and pay incurred expenses associated with the early redemptions. See Note 11 for further information.

CenterPoint Energy’s sales of equity securities during the nine months ended September 30, 2022 are as follows:


Equity Security/Date Sold	Units Sold	Proceeds (1)
		(in millions)
Energy Transfer Common Units
February and March 2022	50,999,768	$	515
Energy Transfer Series G Preferred Units
March 2022	192,390	$	187

(1)Proceeds are net of transaction costs.

Gains and losses on equity securities, net of transaction costs, are recorded in Gain (Loss) on Equity Securities in CenterPoint Energy’s Condensed Statements of Consolidated Income.


	Gains (Losses) on Equity Securities
	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
AT&T Common	$	(57)	$	(18)	$	(94)	$	(18)
Charter Common	(144)		6		(304)		58
WBD Common	(5)		—		28		—
Energy Transfer Common Units	—		—		95		—
Energy Transfer Series G Preferred Units	—		—		(9)		—
Other	—		—		—		—
Total	$	(206)	$	(12)	$	(284)	$	40

CenterPoint Energy recorded net unrealized losses of $206 million and $370 million for the three and nine months ended September 30, 2022 and net unrealized loss of $12 million and net unrealized gain of $40 million for the three and nine months ended September 30, 2021 respectively, for equity securities held as of September 30, 2022 and 2021.

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CenterPoint Energy and its subsidiaries hold shares of certain securities detailed in the table below, which are classified as trading securities. Shares of AT&T Common, Charter Common and WBD Common are expected to be held to facilitate CenterPoint Energy’s ability to meet its obligation under the ZENS.


	Shares Held		Carrying Value
	September 30, 2022	December 31, 2021	September 30, 2022		December 31, 2021
			(in millions)
AT&T Common	10,212,945	10,212,945	$	157	$	251
Charter Common	872,503	872,503	265		569
WBD Common	2,470,685	—	28		—
Energy Transfer Common Units	—	50,999,768	—		420
Energy Transfer Series G Preferred Units	—	192,390	—		196
Other			2		3
Total			$	452	$	1,439

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1.0 billion of which $828 million remained outstanding as of September 30, 2022. Each ZENS is exchangeable at the holder’s option at any time for an amount of cash equal to 95% of the market value of the reference shares attributable to such note. The number and identity of the reference shares attributable to each ZENS are adjusted for certain corporate events.

CenterPoint Energy’s reference shares for each ZENS consisted of the following:


	September 30, 2022	December 31, 2021
	(in shares)
AT&T Common	0.7185	0.7185
Charter Common	0.061382	0.061382
WBD Common	0.173817	—

CenterPoint Energy pays interest on the ZENS at an annual rate of 2% plus the amount of any quarterly cash dividends paid in respect of the reference shares attributable to the ZENS. The principal amount of the ZENS is subject to increases or decreases to the extent that the annual yield from interest and cash dividends on the reference shares attributable to the ZENS is less than or more than 2.309%. The adjusted principal amount is defined in the ZENS instrument as “contingent principal.” As of September 30, 2022, the ZENS, having an original principal amount of $828 million and a contingent principal amount of $29 million, were outstanding and were exchangeable, at the option of the holders, for cash equal to 95% of the market value of the reference shares attributable to the ZENS.

On May 17, 2021, AT&T announced that it had entered into a definitive agreement with Discovery, Inc. to combine their media assets into a new publicly traded company, Warner Bros. Discovery. The transaction closed on April 8, 2022. Pursuant to the definitive agreement, AT&T shareholders received 0.241917 shares of WBD Common for each share of AT&T Common owned, representing 71% of the new company. Upon the closing of the transaction, reference shares attributable to ZENS now consist of 0.7185 shares of AT&T Common, 0.061382 shares of Charter Common and 0.173817 shares of WBD Common.

(11) Short-term Borrowings and Long-term Debt

Inventory Financing. CenterPoint Energy’s and CERC’s Natural Gas businesses have third-party AMAs associated with their utility distribution service in Indiana, Louisiana, Minnesota, Mississippi and Texas. The AMAs have varying terms, the longest of which expires in 2027. Pursuant to the provisions of the agreements, CenterPoint Energy’s and CERC’s Natural Gas either sells natural gas to the asset manager and agrees to repurchase an equivalent amount of natural gas throughout the year at the same cost, or simply purchases its full natural gas requirements at each delivery point from the asset manager. These transactions are accounted for as an inventory financing. CenterPoint Energy and CERC had $14 million and $7 million outstanding obligations related to the AMAs as of September 30, 2022 and December 31, 2021, respectively, recorded in Short-term borrowings on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets. Outstanding obligations related to third-party AMAs associated with utility distribution service in Arkansas and Oklahoma of $36 million as of December 31, 2021 are reflected in current liabilities held for sale on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets. See Note 3 for further information.

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Debt Transactions. During the nine months ended September 30, 2022, in addition to CERC’s debt exchange discussed further below, the following debt instruments were issued or incurred:


Registrant	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
	(in millions)



Houston Electric	February 2022	General Mortgage Bonds (1)	$	300	3.00%	2032
Houston Electric	February 2022	General Mortgage Bonds (1)	500		3.60%	2052
Houston Electric	September 2022	General Mortgage Bonds (2)	500		4.45%	2032
Houston Electric	September 2022	General Mortgage Bonds (2)	300		4.85%	2052
		Total Houston Electric	1,600
CERC	June 2022	Senior Notes (3)	500		4.40%	2032
CERC	August 2022	Term Loan (4)	500		SOFR (5) + 0.70%	2023
		Total CERC	1,000
		Total CenterPoint Energy	$	2,600

(1)Total proceeds, net of discounts and issuance expenses and fees, of approximately $784 million were used for general limited liability company purposes, including capital expenditures and the repayment of all or a portion of Houston Electric’s borrowings under the CenterPoint Energy money pool.

(2)Total proceeds, net of discounts and issuance expenses and fees, of approximately $789 million were used for general limited liability company purposes, including capital expenditures, the repayment of all or a portion of Houston Electric’s borrowings under the CenterPoint Energy money pool and the redemption of outstanding general mortgage bonds discussed below.

(3)Total proceeds, net of discounts and issuance expenses and fees, of approximately $495 million were used for general corporate purposes, including the issuance by CERC Corp.’s current subsidiaries, Indiana Gas and VEDO, of intercompany notes to CERC Corp. in June 2022; these subsidiaries used the funds to repay intercompany debt owed to VUH in connection with the Restructuring in June 2022.

(4)Total proceeds, net of transaction expenses and fees, of approximately $500 million were used for general corporate purposes, including the repayment of CERC’s outstanding commercial paper balances.

(5)As defined in the term loan agreement, which includes an adjustment of 0.10% per annum.

Debt Exchange. As a part of the Restructuring, on May 27, 2022, CERC Corp. and VUH completed an exchange with holders of VUH PPNs whereby CERC Corp. issued new senior notes with an aggregate principal amount of $302 million to such holders in exchange for all of their outstanding VUH PPNs with an aggregate principal amount of $302 million. The new CERC Corp. senior notes have the same principal amount, interest rate, and payment and maturity dates as the VUH PPNs for which they were exchanged. As a result of the exchange, CERC Corp. became the creditor for the PPNs originally issued by VUH, and CERC Corp. received $302 million of cash from VUH on June 30, 2022 in full repayment of the VUH PPNs. Orders received from the IURC and PUCO allow the reissuance of existing debt of Indiana Gas and VEDO to CERC, to continue to amortize existing issuance expenses and discounts, and to treat any potential exchange fees as discounts to be amortized over the life of the debt.

On September 6, 2022, CERC Corp. and VUH announced that CERC Corp. had commenced an offer to eligible holders to exchange any and all outstanding 6.10% senior notes due 2035 issued by Vectren Utility Holdings, Inc. (predecessor of VUH) for (1) up to $75 million aggregate principal amount of new senior notes issued by CERC Corp. and (2) cash. The new CERC Corp. senior notes issued in the exchange offer have the same interest rate and payment and maturity dates as the VUH notes for which they were exchanged. On October 5, 2022, in connection with the settlement of the exchange offer, CERC Corp. issued $75 million aggregate principal amount of 6.10% senior notes due 2035 in exchange for all outstanding VUH senior notes.

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Debt Repayments and Redemptions. During the nine months ended September 30, 2022, the following debt instruments were repaid at maturity or redeemed prior to maturity with proceeds received from the sale of Energy Transfer units discussed further in Note 10:


Registrant	Repayment/Redemption Date	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
			(in millions)
CERC (1)	January 2022	Floating Rate Senior Notes	$	425	Three-month LIBOR plus 0.5%	2023
		Total CERC	425
Houston Electric	August 2022	General Mortgage Bonds	300		2.25%	2022
		Total Houston Electric	300
CenterPoint Energy (2)	January 2022	First Mortgage Bonds	5		0.82%	2022
CenterPoint Energy (3)	March 2022	Senior Notes	250		3.85%	2024
CenterPoint Energy (4)	March 2022	Senior Notes	350		4.25%	2028
		Total CenterPoint Energy	$	1,330

(1)In January 2022, CERC provided notice of partial redemption, and on January 31, 2022, CERC redeemed a portion ($425 million) of the outstanding $1 billion aggregate principal amount of the series at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest on the principal amount being redeemed.

(2)First Mortgage Bonds issued by SIGECO.

(3)In March 2022, CenterPoint Energy provided notice of redemption, and on March 31, 2022, CenterPoint Energy redeemed all of the remaining outstanding senior notes of the series at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest of approximately $2 million, the write off of issuance costs of $1 million and an applicable make-whole premium of approximately $7 million, for a total redemption price of $260 million.

(4)In March 2022, CenterPoint Energy provided notice of partial redemption, and on March 31, 2022, CenterPoint Energy redeemed a portion ($350 million) of the outstanding $500 million aggregate principal amount of the series at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest of approximately $6 million, the write off of issuance costs of $3 million and an applicable make-whole premium of approximately $34 million, for a total redemption price of $393 million.

Additionally, in October 2022, Houston Electric redeemed $200 million aggregate principal amount of its outstanding 5.60% general mortgage bonds due 2023 at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest of approximately $3 million and an applicable make-whole premium of approximately $2 million, for a total redemption price of $205 million.

Credit Facilities.

The Registrants had the following revolving credit facilities as of September 30, 2022:


Execution Date	Registrant	Size of Facility		Draw Rate of LIBOR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of September 30, 2022 (2)	Termination Date
		(in millions)
February 4, 2021	CenterPoint Energy	$	2,400	1.625%	65.0%	(3)	59.9%	February 4, 2024


February 4, 2021	Houston Electric	300		1.375%	67.5%	(3)	52.3%	February 4, 2024
February 4, 2021	CERC	900		1.250%	65.0%		49.8%	February 4, 2024
	Total	$	3,600

(1)Based on current credit ratings.

(2)As defined in the revolving credit facility agreements, excluding Securitization Bonds.

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(3)For CenterPoint Energy and Houston Electric, the financial covenant limit will temporarily increase to 70% if Houston Electric experiences damage from a natural disaster in its service territory and CenterPoint Energy certifies to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive 12-month period, all or part of which Houston Electric intends to seek to recover through securitization financing. Such temporary increase in the financial covenant would be in effect from the date CenterPoint Energy delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of CenterPoint Energy’s certification or (iii) the revocation of such certification.

On June 30, 2022, in connection with the Restructuring, VUH repaid in full all outstanding indebtedness and terminated all remaining commitments and other obligations under its $400 million amended and restated credit agreement dated as of February 4, 2021. VUH did not incur any penalties in connection with the early termination.

The Registrants, including the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of September 30, 2022.

The table below reflects the utilization of the Registrants’ respective revolving credit facilities:


	September 30, 2022								December 31, 2021
Registrant	Loans		Letters of Credit		Commercial Paper (1)		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper (1)		Weighted Average Interest Rate
	(in millions, except weighted average interest rate)
CenterPoint Energy	$	—	$	11	$	454	3.22	%	$	—	$	11	$	1,400	0.34	%
CenterPoint Energy (2)	—		—		—		—	%	—		—		350		0.21	%

Houston Electric	—		—		—		—	%	—		—		—		—	%
CERC	—		—		575		3.38	%	—		—		899		0.26	%
Total	$	—	$	11	$	1,029			$	—	$	11	$	2,649

(1)Outstanding commercial paper generally has maturities of 60 days or less and each Registrants’ commercial paper program is backstopped by such Registrants’ long-term credit facilities. Houston Electric does not have a commercial paper program.

(2)This credit facility was entered into by VUH and was guaranteed by SIGECO, Indiana Gas and VEDO. This credit facility was terminated in connection with the Restructuring, as discussed above.

Liens. As of September 30, 2022, Houston Electric’s assets were subject to liens securing approximately $6.3 billion of general mortgage bonds, including approximately $68 million held in trust to secure pollution control bonds that mature in 2028 for which CenterPoint Energy is obligated. The general mortgage bonds that are held in trust to secure pollution control bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations. As of September 30, 2022, Houston Electric could issue approximately $4.3 billion of additional general mortgage bonds on the basis of retired bonds and 70% of property additions.

Other. As of September 30, 2022, certain financial institutions agreed to issue, from time to time, up to $20 million of letters of credit on behalf of Vectren and certain of its subsidiaries in exchange for customary fees. As of September 30, 2022, such financial institutions had issued $1 million of letters of credit on behalf of Vectren and certain of its subsidiaries.

(12) Income Taxes

The Registrants reported the following effective tax rates:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
CenterPoint Energy - Continuing operations (1)	27	%	18	%	26	%	9	%
CenterPoint Energy - Discontinued operations	—	%	18	%	—	%	22	%
Houston Electric (2)	21	%	18	%	21	%	16	%
CERC (3)(4)	170	%	11	%	25	%	12	%

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(1)CenterPoint Energy’s higher effective tax rate on income from continuing operations for the three and nine months ended September 30, 2022 compared to the same periods ended September 30, 2021 was primarily driven by the impact of the non-deductible goodwill associated with the sale of the Natural Gas businesses in Arkansas and Oklahoma, and a decrease in EDIT amortization of the net regulatory EDIT liability.

(2)Houston Electric’s higher effective tax rate for the three and nine months ended September 30, 2022 compared to the same period in 2021 was primarily driven by a decrease in the amount of amortization of the net regulatory EDIT liability.

(3)CERC’s higher effective tax rate for the three months ended September 30, 2022 compared to the same period ended September 30, 2021 was primarily driven by the impact of the non-deductible goodwill associated with the sale of the Natural Gas businesses in Arkansas and Oklahoma, and a decrease in EDIT amortization of the net regulatory EDIT liability.

(4)CERC’s higher effective tax rate for the nine months ended September 30, 2022 compared to the same period ended September 30, 2021 was primarily driven by the impact of the non-deductible goodwill associated with the sale of the Natural Gas businesses in Arkansas and Oklahoma offset by an increase in EDIT amortization of the net regulatory EDIT liability and the 2021 deferred state tax benefit for the revaluation of deferred tax assets and liabilities due to both the Arkansas and Oklahoma gas assets being held for sale and Louisiana and Oklahoma tax rates changes as well as the release of the valuation allowance on certain Louisiana NOLs in the quarter ended June 30, 2021.

CenterPoint Energy reported a net uncertain tax liability, inclusive of interest and penalties, of $5 million as of September 30, 2022. The Registrants believe that it is reasonably possible that a decrease of less than $1 million in unrecognized tax benefits may occur in the next 12 months as a result of a lapse of statutes on older exposures, a tax settlement, and/or a resolution of open audits.

Tax Audits and Settlements. Tax years through 2018 have been audited and settled with the IRS for CenterPoint Energy. For the 2019-2022 tax years, the Registrants are participants in the IRS’s Compliance Assurance Process. Vectren’s pre-Merger

2014-2019 tax years are currently under audit by the IRS.

(13) Commitments and Contingencies

(a)Purchase Obligations (CenterPoint Energy and CERC)

Commitments include minimum purchase obligations related to CenterPoint Energy’s and CERC’s Natural Gas reportable segment and CenterPoint Energy’s Electric reportable segment. A purchase obligation is defined as an agreement to purchase goods or services that is enforceable and legally binding on the registrant and that specifies all significant terms, including: fixed or minimum quantities to be purchased; fixed, minimum or variable price provisions; and the approximate timing of the transaction. Contracts with minimum payment provisions have various quantity requirements and durations and are not classified as non-trading derivative assets and liabilities in CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets as of September 30, 2022 and December 31, 2021. These contracts meet an exception as “normal purchases contracts” or do not meet the definition of a derivative. Natural gas and coal supply commitments also include transportation contracts that do not meet the definition of a derivative.

On February 9, 2021, Indiana Electric entered into a BTA with a subsidiary of Capital Dynamics. Pursuant to the BTA, Capital Dynamics, with its partner Tenaska, originally planned to build a 300 MW solar array in Posey County, Indiana through a special purpose entity, Posey Solar. Upon completion of construction, currently projected to be placed in service in 2024, and subject to IURC approval, which was received on October 27, 2021, Indiana Electric will acquire Posey Solar and its solar array assets for a fixed purchase price. Due to rising cost for the project, caused in part by supply chain issues in the energy industry, the rising cost of commodities and community feedback, CenterPoint Energy, along with Capital Dynamics, announced plans in January 2022 to downsize the project to approximately 200 MW. Indiana Electric collaboratively agreed to the scope change and is currently working through contract negotiations, contingent on further IURC review and approval.

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As of September 30, 2022, other than discussed below, undiscounted minimum purchase obligations are approximately:


	CenterPoint Energy				CERC
	Natural Gas and Coal Supply		Other (1)		Natural Gas Supply
	(in millions)
Remaining three months of 2022	$	343	$	79	$	289
2023	1,046		567		923
2024	898		385		855
2025	669		63		627
2026	510		33		474
2027	442		74		406
2028 and beyond	2,135		571		2,019

(1)CenterPoint Energy’s undiscounted minimum payment obligations related to PPAs with commitments ranging from 15 to 25 years and its purchase commitments under its BTA in Posey County, Indiana and its BTA in Pike County, Indiana are included above. The remaining undiscounted payment obligations relate primarily to technology hardware and software agreements.

Excluded from the table above are estimates for cash outlays from other PPAs through Indiana Electric that do not have minimum thresholds but do require payment when energy is generated by the provider. Costs arising from certain of these commitments are pass-through costs, generally collected dollar-for-dollar from retail customers through regulator-approved cost recovery mechanisms.

(b) Guarantees and Product Warranties (CenterPoint Energy)

In the normal course of business, Energy Systems Group enters into contracts requiring it to timely install infrastructure, operate facilities, pay vendors and subcontractors and support warranty obligations and, at times, issue payment and performance bonds and other forms of assurance in connection with these contracts.

Specific to Energy Systems Group’s role as a general contractor in the performance contracting industry, as of September 30, 2022, there were 62 open surety bonds supporting future performance with an aggregate face amount of approximately $659 million. Energy Systems Group’s exposure is less than the face amount of the surety bonds and is limited to the level of uncompleted work under the contracts. As of September 30, 2022, approximately 40% of the work was yet to be completed on projects with open surety bonds. Further, various subcontractors issue surety bonds to Energy Systems Group. In addition to these performance obligations, Energy Systems Group also warrants the functionality of certain installed infrastructure generally for one year and the associated energy savings over a specified number of years. As of September 30, 2022, there were 34 warranties totaling $529 million and an additional $1.3 billion in energy savings commitments not guaranteed by Vectren. Since Energy Systems Group’s inception in 1994, CenterPoint Energy believes Energy Systems Group has had a history of generally meeting its performance obligations and energy savings guarantees and its installed products have operated effectively. CenterPoint Energy assessed the fair value of its obligation for such guarantees as of September 30, 2022 and no amounts were recorded on CenterPoint Energy’s Condensed Consolidated Balance Sheets.

CenterPoint Energy issues parent company level guarantees to certain vendors, customers and other commercial counterparties of Energy Systems Group. These guarantees do not represent incremental consolidated obligations, but rather, represent guarantees of subsidiary obligations to allow those subsidiaries to conduct business without posting other forms of assurance. As of September 30, 2022, CenterPoint Energy, primarily through Vectren, has issued parent company level guarantees supporting Energy Systems Group’s obligations. For those obligations where potential exposure can be estimated, management estimates the maximum exposure under these guarantees to be approximately $534 million as of September 30, 2022. This exposure primarily relates to energy savings guarantees on federal energy savings performance contracts. Other parent company level guarantees, certain of which do not contain a cap on potential liability, have been issued in support of federal operations and maintenance projects for which a maximum exposure cannot be estimated based on the nature of the projects. While there can be no assurance that performance under any of these parent company guarantees will not be required in the future, CenterPoint Energy considers the likelihood of a material amount being incurred as remote.

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(c)Guarantees and Product Warranties (CenterPoint Energy and CERC)

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell the Energy Services Disposal Group. The transaction closed on June 1, 2020. In the normal course of business prior to June 1, 2020, the Energy Services Disposal Group through CES, traded natural gas under supply contracts and entered into natural gas related transactions under transportation, storage and other contracts. In connection with the Energy Services Disposal Group’s business activities prior to the closing of the sale of the Energy Services Disposal Group on June 1, 2020, CERC Corp. issued guarantees to certain of CES’s counterparties to guarantee the payment of CES’s obligations. When CES remained wholly owned by CERC Corp., these guarantees did not represent incremental consolidated obligations, but rather, these guarantees represented guarantees of CES’s obligations to allow it to conduct business without posting other forms of assurance.

Under the terms of the Equity Purchase Agreement, Symmetry Energy Solutions Acquisition must generally use reasonable best efforts to replace existing CERC Corp. guarantees with credit support provided by a party other than CERC Corp. as of and after the closing of the transaction. As of September 30, 2022, management believes the exposure that remained outstanding under CERC Corp. guarantees issued prior to the closing of the transaction on June 1, 2020 is immaterial.

CenterPoint Energy and CERC recorded no amounts on their respective Condensed Consolidated Balance Sheets as of September 30, 2022 and December 31, 2021 related to the performance of these guarantees.

(d) Legal, Environmental and Other Matters

Legal Matters

Litigation Related to the February 2021 Winter Storm Event. Various legal matters are still proceeding with respect to the February 2021 Winter Storm Event. As of September 30, 2022, there are approximately 190 related lawsuits, which are pending, and in approximately 130 CenterPoint Energy, Utility Holding, LLC and Houston Electric, along with numerous other entities, have been named as defendants. Like other Texas energy companies and TDUs, CenterPoint Energy and Houston Electric have become involved in certain investigations, litigation and other regulatory and legal proceedings regarding their efforts to restore power and their compliance with NERC, ERCOT and PUCT rules and directives. CenterPoint Energy, Utility Holding, LLC, and Houston Electric, along with hundreds of other defendants (including ERCOT, power generation companies, other TDUs, natural gas producers, retail electric providers, and other entities) have received, and may continue to receive, claims and lawsuits filed by plaintiffs alleging wrongful death, personal injury, property damage and other injuries and damages. The litigation is now consolidated in Texas state court in Harris County, Texas, as part of a multi-district litigation proceeding. The judge overseeing the multi-district litigation has issued an initial case management order and stayed all proceedings and discovery, including discovery related to damages. Per the case management order, the judge will first entertain dispositive motions in five representative or “bellwether” cases; the judge held hearings on them in mid-October and will likely rule on them later in 2022, which ruling will likely be appealed. Until the judge rules on those motions and any appeals of such rulings are resolved, further proceedings and discovery will likely remain stayed. CenterPoint Energy, Utility Holding, LLC, and Houston Electric intend to vigorously defend themselves against the claims raised.

CenterPoint Energy and Houston Electric have also responded to inquiries from the Texas Attorney General and the Galveston County District Attorney’s Office, and various other regulatory and governmental entities have conducted or are conducting inquiries, investigations and other reviews of the February 2021 Winter Storm Event and the efforts made by various entities to prepare for, and respond to, the event, including the electric generation shortfall issues. Such other entities include the United States Congress, FERC, NERC, Texas RE, ERCOT, Texas government entities and officials such as the Texas Governor’s office, the Texas Legislature, the PUCT, the City of Houston and other municipal and county entities in Houston Electric’s service territory. Additionally, CenterPoint Energy and CERC have responded to inquiries from several state Attorneys General.

To date, there have not been demands, quantification, disclosure or discovery of damages by any party to the litigation that are sufficient to enable CenterPoint Energy and its subsidiaries to estimate exposure. Given that, as well as the preliminary nature of the proceedings, the numerosity of parties and complexity of issues involved, and the uncertainties of litigation, CenterPoint Energy and its subsidiaries are unable to predict the outcome or consequences of any of the foregoing matters or to estimate a range of potential losses. CenterPoint Energy and its subsidiaries have general and excess liability insurance policies that provide coverage for third party bodily injury and property damage claims.

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Environmental Matters

MGP Sites. CenterPoint Energy, CERC and their predecessors, including predecessors of Vectren, operated MGPs in the past. The costs CenterPoint Energy or CERC, as applicable, expect to incur to fulfill their respective obligations are estimated by management using assumptions based on actual costs incurred, the timing of expected future payments and inflation factors, among others. While CenterPoint Energy and CERC have recorded obligations for all costs which are probable and estimable, including amounts they are presently obligated to incur in connection with activities at these sites, it is possible that future events may require remedial activities which are not presently foreseen, and those costs may not be subject to PRP or insurance recovery.

(i)Minnesota MGPs (CenterPoint Energy and CERC). With respect to certain Minnesota MGP sites, CenterPoint Energy and CERC have completed state-ordered remediation and continue state-ordered monitoring and water treatment. CenterPoint Energy and CERC recorded a liability as reflected in the table below for continued monitoring and any future remediation required by regulators in Minnesota.

(ii)Indiana MGPs (CenterPoint Energy and CERC). In the Indiana Gas service territory, the existence, location and certain general characteristics of 26 gas manufacturing and storage sites have been identified for which CenterPoint Energy and CERC may have some remedial responsibility. A remedial investigation/feasibility study was completed at one of the sites under an agreed upon order between Indiana Gas and the IDEM, and a Record of Decision was issued by the IDEM in January 2000. The remaining sites have been submitted to the IDEM’s VRP. CenterPoint Energy has also identified its involvement in 5 manufactured gas plant sites in SIGECO’s service territory, all of which are currently enrolled in the IDEM’s VRP. CenterPoint Energy is currently conducting some level of remedial activities, including groundwater monitoring at certain sites.

(iii)Other MGPs (CenterPoint Energy and CERC). In addition to the Minnesota and Indiana sites, the EPA and other regulators have investigated MGP sites that were owned or operated by CenterPoint Energy or CERC or may have been owned by one of their former affiliates.

Total costs that may be incurred in connection with addressing these sites cannot be determined at this time. The estimated accrued costs are limited to CenterPoint Energy’s and CERC’s share of the remediation efforts and are therefore net of exposures of other PRPs. The estimated range of possible remediation costs for the sites for which CenterPoint Energy and CERC believe they may have responsibility was based on remediation continuing for the minimum time frame given in the table below.


	September 30, 2022
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	16	$	14
Minimum estimated remediation costs	12		11
Maximum estimated remediation costs	51		44
Minimum years of remediation	5		5
Maximum years of remediation	50		50

The cost estimates are based on studies of a site or industry average costs for remediation of sites of similar size. The actual remediation costs will depend on the number of sites to be remediated, the participation of other PRPs, if any, and the remediation methods used.

CenterPoint Energy and CERC do not expect the ultimate outcome of these matters to have a material adverse effect on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC.

Asbestos. Some facilities owned by the Registrants or their predecessors contain or have contained asbestos insulation and other asbestos-containing materials. The Registrants are from time to time named, along with numerous others, as defendants in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos, and the Registrants anticipate that additional claims may be asserted in the future. Although their ultimate outcome cannot be predicted at this time, the Registrants do not expect these matters, either individually or in the aggregate, to have a material adverse effect on their financial condition, results of operations or cash flows.

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CCR Rule (CenterPoint Energy). In April 2015, the EPA finalized its CCR Rule, which regulates ash as non-hazardous material under the RCRA. The final rule allows beneficial reuse of ash, and the majority of the ash generated by Indiana Electric’s generating plants will continue to be reused. In July 2018, the EPA released its final CCR Rule Phase I Reconsideration which extended the deadline to October 31, 2020 for ceasing placement of ash in ponds that exceed groundwater protections standards or that fail to meet location restrictions. In August 2019, the EPA proposed additional “Part A” amendments to its CCR Rule with respect to beneficial reuse of ash and other materials. Further “Part B” amendments, which related to alternate liners for CCR surface impoundments and the surface impoundment closure process, were published in March 2020. The Part A amendments were finalized in August 2020 and extended the deadline to cease placement of ash in ponds to April 11, 2021, discussed further below. The Part A amendments do not restrict Indiana Electric’s current beneficial reuse of its fly ash. CenterPoint Energy evaluated the Part B amendments to determine potential impacts and determined that the Part B amendments did not have an impact on its current plans.

Indiana Electric has three ash ponds, two at the F.B. Culley facility (Culley East and Culley West) and one at the A.B. Brown facility. Under the existing CCR Rule, Indiana Electric is required to perform integrity assessments, including ground water monitoring, at its F.B. Culley and A.B. Brown generating stations. The ground water studies are necessary to determine the remaining service life of the ponds and whether a pond must be retrofitted with liners or closed in place. Indiana Electric’s Warrick generating unit is not included in the scope of the CCR Rule as this unit has historically been part of a larger generating station that predominantly serves an adjacent industrial facility. Preliminary groundwater monitoring indicates potential groundwater impacts very close to Indiana Electric’s ash impoundments, and further analysis is ongoing. The CCR Rule required companies to complete location restriction determinations by October 18, 2018. Indiana Electric completed its evaluation and determined that one F.B. Culley pond (Culley East) and the A.B. Brown pond fail the aquifer placement location restriction. As a result of this failure, Indiana Electric was required to cease disposal of new ash in the ponds and commence closure of the ponds by April 11, 2021, unless approved for an extension. CenterPoint Energy has applied for the extensions available under the CCR Rule that would allow Indiana Electric to continue to use the ponds through October 15, 2023. The EPA is still reviewing industry extension requests, including CenterPoint Energy’s extension request for the Culley East pond. Companies can continue to operate ponds pending completion of the EPA’s evaluation of the requests for extension. If the EPA denies a full extension request, that denial may result in increased and potentially significant operational costs in connection with the accelerated implementation of an alternative ash disposal system or may adversely impact Indiana Electric’s future operations. Failure to comply with a cease waste receipt could also result in an enforcement proceeding, resulting in the imposition of fines and penalties. On October 5, 2022, EPA issued a proposed conditional approval of the Part A extension request for the A.B. Brown pond. EPA’s determination will be up for public comment for thirty days from October 19. On April 24, 2019, Indiana Electric received an order from the IURC approving recovery in rates of costs associated with the closure of the Culley West pond, which has already completed closure activities. On August 14, 2019, Indiana Electric filed its petition with the IURC for recovery of costs associated with the closure of the A.B. Brown ash pond, which would include costs associated with the excavation and recycling of ponded ash. This petition was subsequently approved by the IURC on May 13, 2020. On October 28, 2020, the IURC approved Indiana Electric’s ECA proceeding, which included the initiation of recovery of the federally mandated project costs.

Indiana Electric continues to refine site specific estimates of closure costs for its 10-acre Culley East pond. In July 2018, Indiana Electric filed a Complaint for Damages and Declaratory Relief against its insurers seeking reimbursement of defense, investigation and pond closure costs incurred to comply with the CCR Rule, and has since reached confidential settlement agreements with its insurers. The proceeds of these settlements will offset costs that have been and will be incurred to close the ponds.

As of September 30, 2022, CenterPoint Energy has recorded an approximate $92 million ARO, which represents the discounted value of future cash flow estimates to close the ponds at A.B. Brown and F.B. Culley. This estimate is subject to change due to the contractual arrangements; continued assessments of the ash, closure methods, and the timing of closure; implications of Indiana Electric’s generation transition plan; changing environmental regulations; and proceeds received from the settlements in the aforementioned insurance proceeding. In addition to these AROs, Indiana Electric also anticipates equipment purchases of between $60 million and $80 million to complete the A.B. Brown closure project.

Clean Water Act Permitting of Groundwater Discharges. In April 2021, the U.S. Supreme Court issued an opinion providing that indirect discharges via groundwater or other non-point sources are subject to permitting and liability under the Clean Water Act when they are the functional equivalent of a direct discharge. The Registrants are evaluating the extent to which this decision will affect Clean Water Act permitting requirements and/or liability for their operations.

Other Environmental. From time to time, the Registrants identify the presence of environmental contaminants during operations or on property where their predecessors have conducted operations. Other such sites involving contaminants may be identified in the future. The Registrants have and expect to continue to remediate any identified sites consistent with state and federal legal obligations. From time to time, the Registrants have received notices, and may receive notices in the future, from

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regulatory authorities or others regarding status as a PRP in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, the Registrants have been, or may be, named from time to time as defendants in litigation related to such sites. Although the ultimate outcome of such matters cannot be predicted at this time, the Registrants do not expect these matters, either individually or in the aggregate, to have a material adverse effect on their financial condition, results of operations or cash flows.

Other Proceedings

The Registrants are involved in other legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. From time to time, the Registrants are also defendants in legal proceedings with respect to claims brought by various plaintiffs against broad groups of participants in the energy industry. Some of these proceedings involve substantial amounts. The Registrants regularly analyze current information and, as necessary, provide accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. The Registrants do not expect the disposition of these matters to have a material adverse effect on the Registrants’ financial condition, results of operations or cash flows.

(14) Earnings Per Share (CenterPoint Energy)

The Series C Preferred Stock issued in May 2020 were considered participating securities since these shares participated in dividends on Common Stock on a pari passu, pro rata, as-converted basis. As a result, beginning June 30, 2020, earnings per share on Common Stock was computed using the two-class method required for participating securities during the periods the Series C Preferred Stock was outstanding. As of May 7, 2021, all of the remaining outstanding Series C Preferred Stock were converted into shares of Common Stock and earnings per share on Common Stock and, as such, the two-class method was no longer applicable beginning June 30, 2021.

Basic earnings per common share is computed by dividing income available to common shareholders from continuing operations by the basic weighted average number of common shares outstanding during the period. Participating securities are excluded from basic weighted average number of common shares outstanding. Diluted earnings per common share is computed by dividing income available to common shareholders from continuing operations by the weighted average number of common shares outstanding, including all potentially dilutive common shares, if the effect of such common shares is dilutive.

Diluted earnings per share reflects the dilutive effect of potential common shares from share-based awards and convertible preferred shares. The dilutive effect of Series B Preferred Stock and Series C Preferred Stock is computed using the if-converted method, as applicable, which assumes conversion of Series B Preferred Stock and Series C Preferred Stock at the beginning of the period, giving income recognition for the add-back of the preferred share dividends, amortization of beneficial conversion feature, and undistributed earnings allocated to preferred shareholders. The dilutive effect of restricted stock is computed using the treasury stock method, as applicable, which includes the incremental shares that would be hypothetically vested in excess of the number of shares assumed to be hypothetically repurchased with the assumed proceeds.

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The following table reconciles numerators and denominators of CenterPoint Energy’s basic and diluted earnings per common share.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions, except per share and share amounts)
Numerator:
Income from continuing operations	$	202	$	150	$	923	$	630
Less: Preferred stock dividend requirement (Note 18)	13		23		37		82


Income available to common shareholders from continuing operations - basic and diluted	189		127		886		548



Income available to common shareholders from discontinued operations - basic and diluted	—		68		—		202
Income available to common shareholders - basic and diluted	$	189	$	195	$	886	$	750
Denominator:
Weighted average common shares outstanding - basic	629,509,000		604,607,000		629,374,000		580,819,000
Plus: Incremental shares from assumed conversions:
Restricted stock	3,559,000		4,775,000		3,559,000		4,775,000

Series C Preferred Stock	—		—		—		15,809,000
Weighted average common shares outstanding - diluted	633,068,000		609,382,000		632,933,000		601,403,000


Anti-dilutive Incremental Shares Excluded from Denominator for Diluted Earnings Computation:

Series B Preferred Stock	—		24,179,000		—		31,962,000


Earnings Per Common Share:
Basic earnings per common share - continuing operations	$	0.30	$	0.21	$	1.41	$	0.94
Basic earnings per common share - discontinued operations	—		0.11		—		0.35
Basic Earnings Per Common Share	$	0.30	$	0.32	$	1.41	$	1.29
Diluted earnings per common share - continuing operations	$	0.30	$	0.21	$	1.40	$	0.91
Diluted earnings per common share - discontinued operations	—		0.11		—		0.34
Diluted Earnings Per Common Share	$	0.30	$	0.32	$	1.40	$	1.25

(15) Reportable Segments

The Registrants’ determination of reportable segments considers the strategic operating units under which its CODM manages sales, allocates resources and assesses performance of various products and services to wholesale or retail customers in differing regulatory environments. Each Registrant’s CODM views net income as the measure of profit or loss for the reportable segments. Certain prior year amounts have been reclassified for discontinued operations as described below. Additionally, during the nine months ended September 30, 2022, CenterPoint Energy sold certain assets previously owned by entities within Corporate and Other to businesses within the Electric and Natural Gas reportable segments. Prior year amounts were reclassified as a result of this transaction in the nine months ended September 30, 2022 and as described in the combined 2021 Form 10-K.

In 2021, CenterPoint Energy’s equity investment in Enable was classified and presented as held for sale and discontinued operations. On December 2, 2021, Enable completed the previously announced Enable Merger pursuant to the Enable Merger Agreement entered into on February 16, 2021. See Note 3 for further information.

As of September 30, 2022, reportable segments by Registrant were as follows:

CenterPoint Energy

•CenterPoint Energy’s Electric reportable segment consisted of electric transmission and distribution services in the Texas gulf coast area in the ERCOT region and electric transmission and distribution services primarily to southwestern Indiana and includes power generation and wholesale power operations in the MISO region.

•CenterPoint Energy’s Natural Gas reportable segment consists of (i) intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Indiana, Louisiana,

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Minnesota, Mississippi, Ohio and Texas; and (ii) permanent pipeline connections through interconnects with various interstate and intrastate pipeline companies through CEIP.

CenterPoint Energy’s Corporate and Other category consists of energy performance contracting and sustainable infrastructure services through Energy Systems Group and other corporate operations which support all of the business operations of CenterPoint Energy.

Houston Electric

•Houston Electric’s single reportable segment consisted of electric transmission services to transmission service customers in the ERCOT region and distribution services to REPs serving the Texas gulf coast area.

CERC

•CERC’s single reportable segment following the Restructuring consisted of (i) intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Indiana, Louisiana, Minnesota, Mississippi, Ohio and Texas; and (ii) permanent pipeline connections through interconnects with various interstate and intrastate pipeline companies through CEIP.

Financial data for reportable segments is as follows, including Corporate and Other and Discontinued Operations for reconciliation purposes:

CenterPoint Energy


	Three Months Ended September 30,
	2022			2021
	Revenues from External Customers			Net Income (Loss)		Revenues from External Customers			Net Income (Loss)
	(in millions)
Electric	$	1,146	(1)	$	234	$	1,056	(1)	$	185
Natural Gas	692			(10)		619			5
Corporate and Other	65			(22)		74			(40)
Continuing Operations	$	1,903		202		$	1,749		150
Discontinued Operations, net				—					68
Consolidated				$	202				$	218

	Nine Months Ended September 30,
	2022			2021
	Revenues from External Customers			Net Income		Revenues from External Customers			Net Income (Loss)
	(in millions)
Electric	$	3,092	(1)	$	489	$	2,823	(1)	$	385
Natural Gas	3,334			416		3,022			308
Corporate and Other	184			18		193			(63)

Continuing Operations	$	6,610		923		$	6,038		630
Discontinued Operations, net				—					202
Consolidated				$	923				$	832

(1)Houston Electric revenues from major external customers are as follows (CenterPoint Energy and Houston Electric):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Affiliates of NRG	$	327	$	285	$	797	$	672
Affiliates of Vistra Energy Corp.	153		128		372		303

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	Total Assets
	September 30, 2022		December 31, 2021
	(in millions)
Electric	$	18,524	$	16,548
Natural Gas	16,796		16,270

Corporate and Other, net of eliminations (1)	1,399		2,523

Continuing Operations	36,719		35,341
Assets Held for Sale	—		2,338
Consolidated	$	36,719	$	37,679

(1)Total assets included pension and other postemployment-related regulatory assets of $424 million and $427 million as of September 30, 2022 and December 31, 2021, respectively.

Houston Electric

Houston Electric consists of a single reportable segment; therefore, a tabular reportable segment presentation has not been included.

CERC

CERC consists of a single reportable segment; therefore, a tabular reportable segment presentation has not been included.

(16) Supplemental Disclosure of Cash Flow Information

The table below provides supplemental disclosure of cash flow information:


	Nine Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	376	$	188	$	67	$	427	$	172	$	96
Income tax payments (refunds), net	340		113		3		(47)		—		(11)
Non-cash transactions:
Accounts payable related to capital expenditures	333		197		145		290		208		124
ROU assets obtained in exchange for lease liabilities (1)	1		—		—		2		—		—

(1) Excludes ROU assets obtained through prepayment of the lease liabilities. See Note 19.

The table below provides a reconciliation of cash, cash equivalents and restricted cash reported in the Condensed Consolidated Balance Sheets to the amount reported in the Condensed Statements of Consolidated Cash Flows:


	September 30, 2022						December 31, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash and cash equivalents (1)	$	114	$	115	$	1	$	230	$	214	$	15
Restricted cash included in Prepaid expenses and other current assets	16		12		—		24		19		—

Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	130	$	127	$	1	$	254	$	233	$	15

(1)Houston Electric’s Cash and cash equivalents as of September 30, 2022 and December 31, 2021 included $110 million and $92 million, respectively, of cash related to the Bond Companies.

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(17) Related Party Transactions (Houston Electric and CERC)

Houston Electric and CERC participate in CenterPoint Energy’s money pool through which they can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the CenterPoint Energy money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper.

The table below summarizes CenterPoint Energy money pool activity:


	September 30, 2022						December 31, 2021
	Houston Electric			CERC			Houston Electric			CERC
	(in millions, except interest rates)
Money pool investments (borrowings) (1)	$	360		$	—		$	(512)		$	(224)
Weighted average interest rate	3.25		%	3.25		%	0.34		%	0.34		%

(1)Included in Accounts and notes receivable (payable)–affiliated companies on Houston Electric’s and CERC’s respective Condensed Consolidated Balance Sheets.

As a result of the Restructuring, CERC acquired Indiana Gas and VEDO, which had notes payable to VUH for borrowings under the VUH money pool in the amount of $217 million and a weighted average interest rate of 0.21% as of December 31, 2021. These notes were repaid to VUH on June 30, 2022 in connection with the Restructuring.

CenterPoint Energy provides some corporate services to Houston Electric and CERC. The costs of services have been charged directly to Houston Electric and CERC using methods that management believes are reasonable. These methods include usage rates, dedicated asset assignment and proportionate corporate formulas based on operating expenses, assets, gross margin, employees and a composite of assets, gross margin and employees. Houston Electric provides certain services to CERC. These services are billed at actual cost, either directly or as an allocation and include fleet services, shop services, geographic services, surveying and right-of-way services, radio communications, data circuit management and field operations. Additionally, CERC provides certain services to Houston Electric. These services are billed at actual cost, either directly or as an allocation and include line locating and other miscellaneous services. These charges are not necessarily indicative of what would have been incurred had Houston Electric and CERC not been affiliates.

Amounts charged for these services were as follows and are included primarily in operation and maintenance expenses:


	Three Months Ended September 30,								Nine Months Ended September 30,
	2022				2021				2022				2021
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Corporate service charges	$	38	$	54	$	46	$	64	$	114	$	163	$	136	$	178
Net affiliate service charges (billings)	3		(3)		(4)		4		(12)		12		(6)		6

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The table below presents transactions among Houston Electric, CERC and their parent, CenterPoint Energy.


	Three Months Ended September 30,								Nine Months Ended September 30,
	2022				2021				2022				2021
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	74	$	13	$	—	$	—	$	141	$	124	$	—	$	—
Cash dividend paid to parent related to the sale of the Arkansas and Oklahoma Natural Gas businesses	—		—		—		—		—		720		—		—
Cash contribution from parent	—		—		—		—		1,143		125		—		—
Net assets acquired in the Restructuring (1)	—		—		—		—		—		2,345		—		—
Non-cash capital contribution from parent in payment for property, plant and equipment below	—		—		—		—		38		54		—		—
Cash paid to parent for property, plant and equipment below	—		—		—		—		65		61		—		—
Property, plant and equipment from parent (2)	—		—		—		—		103		115		—		—

(1) The Restructuring was a common control transaction that required the recasting of financial information to the earliest period presented. Therefore, the net asset transfer is not reflected during the current period on CERC’s Condensed Statements of Consolidated Changes in Equity.

(2) Property, plant and equipment purchased from CenterPoint Energy at its net carrying value on the date of purchase.

Common Control Transaction

The Restructuring has been accounted for as a common control transaction as there is no change in the control over the assets acquired and liabilities assumed. As a result, CERC acquired these businesses at CenterPoint Energy’s historical basis in these entities and prior year amounts were recast to reflect the Restructuring as if it occurred at the earliest period presented for which CenterPoint Energy had common control.

The following table presents the as reported and recast amounts for CERC’s Condensed Consolidated Balance Sheet.


	December 31, 2021
	As Reported		Recast
	(in millions)
Total Assets	$	11,110	$	16,153
Total Liabilities	8,109		11,020
Retained Earnings	765		1,017
Total Equity	3,001		5,133

The following table presents the as reported and recast amounts for CERC’s Condensed Statements of Consolidated Income.


	Three Months Ended September 30, 2021				Nine Months Ended September 30, 2021
	As Reported		Recast		As Reported		Recast
	(in millions)
Net income (loss)	$	(1)	$	8	$	208	$	303

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(18) Equity

Dividends Declared and Paid (CenterPoint Energy)


	Dividends Declared Per Share								Dividends Paid Per Share
	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Common Stock	$	0.360	$	0.330	$	0.530	$	0.490	$	0.180	$	0.160	$	0.520	$	0.480
Series A Preferred Stock	30.625		30.625		30.625		30.625		30.625		30.625		61.250		61.250
Series B Preferred Stock	—		17.500		—		35.000		—		17.500		—		52.500
Series C Preferred Stock (1)	—		—		—		—		—		—		—		0.160

(1)The Series C Preferred Stock was entitled to participate in any dividend or distribution (excluding those payable in Common Stock) with the Common Stock on a pari passu, pro rata, as-converted basis. The per share amount reflects the dividend per share of Common Stock as if the Series C Preferred Stock were converted into Common Stock. All of the outstanding Series C Preferred Stock was converted to Common Stock during April and May 2021.

Preferred Stock (CenterPoint Energy)


	Liquidation Preference Per Share		Shares Outstanding as of		Outstanding Value as of
			September 30, 2022	December 31, 2021	September 30, 2022		December 31, 2021
	(in millions, except shares and per share amounts)
Series A Preferred Stock	$	1,000	800,000	800,000	$	790	$	790


			800,000	800,000	$	790	$	790

Income Allocated to Preferred Shareholders (CenterPoint Energy)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in millions)
Series A Preferred Stock	$	13	$	12	$	37	$	37
Series B Preferred Stock	—		11		—		45



Total income allocated to preferred shareholders	$	13	$	23	$	37	$	82

Temporary Equity (CenterPoint Energy)

On the approval and recommendation of the Compensation Committee and approval of the Board (acting solely through its independent directors), CenterPoint Energy entered into a retention incentive agreement with David J. Lesar, President and Chief Executive Officer of CenterPoint Energy, dated July 20, 2021. Under the terms of the retention incentive agreement, Mr. Lesar will receive equity-based awards under CenterPoint Energy’s LTIP covering a total of 1 million shares of Common Stock (Total Stock Award) to be granted in multiple annual awards. Mr. Lesar received 400 thousand restricted stock units in July 2021 that will vest in December 2022 and 400 thousand restricted stock units in February 2022 that will vest in December 2023. In February 2023, restricted stock units covering the remaining 200 thousand shares, or such lesser number of restricted stock units as may be required pursuant to the annual individual award limitations under CenterPoint Energy’s LTIP, will be awarded to Mr. Lesar and will vest in December 2023. In the event any shares under the Total Stock Award remain unawarded, in February 2024, a fully vested stock bonus award of the remaining shares will be granted. For accounting purposes, the 1 million shares under the Total Stock Award, consisting of both the awarded and unawarded equity-based awards described above, were considered granted in July 2021. In the event of death, disability, termination without cause or resignation for good reason, as defined in the retention incentive agreement, that occurs prior to the full Total Stock Award being awarded, CenterPoint Energy will pay a lump sum cash payment equal to the value of the unawarded equity-based awards, based on the closing trading price of Common Stock on the date of the event’s occurrence. Because the unawarded equity-based awards are redeemable for cash

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upon events that are not probable at the grant date, the equity associated with the unawarded equity-based awards will be classified as Temporary Equity on CenterPoint Energy’s Condensed Consolidated Balance Sheets.

Accumulated Other Comprehensive Income (Loss)

Changes in accumulated comprehensive income (loss) are as follows:


	Three Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Beginning Balance	$	(85)	$	—	$	10	$	(85)	$	—	$	10
Other comprehensive income (loss) before reclassifications:
Remeasurement of pension and other postretirement plans	(10)		—		—		—		—		—


Amounts reclassified from accumulated other comprehensive income (loss):
Prior service cost (1)	—		—		—		1		—		—
Actuarial losses (1)	2		—		—		1		—		—
Settlement (2)	1		—		—		3		—		—
Reclassification of deferred loss from cash flow hedges realized in net income	—		—		—		1		—		—
Tax benefit (expense)	9		—		—		(1)		—		—
Net current period other comprehensive income (loss)	2		—		—		5		—		—
Ending Balance	$	(83)	$	—	$	10	$	(80)	$	—	$	10

	Nine Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Beginning Balance	$	(64)	$	—	$	10	$	(90)	$	—	$	10
Other comprehensive income (loss) before reclassifications:
Remeasurement of pension and other postretirement plans	(44)		—		—		—		—		—

Other comprehensive income (loss) from unconsolidated affiliates	—		—		—		2		—		—
Amounts reclassified from accumulated other comprehensive income (loss):
Prior service cost (1)	1		—		—		1		—		—
Actuarial losses (1)	4		—		—		5		—		—
Settlement (2)	14		—		—		3		—		—
Reclassification of deferred loss from cash flow hedges realized in net income	1		—		—		1		—		—

Tax benefit (expense)	5		—		—		(2)		—		—
Net current period other comprehensive income (loss)	(19)		—		—		10		—		—
Ending Balance	$	(83)	$	—	$	10	$	(80)	$	—	$	10

(1)Amounts are included in the computation of net periodic cost and are reflected in Other income, net in each of the Registrants’ respective Condensed Statements of Consolidated Income.

(2)Amounts presented represent a one-time, non-cash settlement cost (benefit), prior to regulatory deferrals, which are required when the total lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of the net periodic cost for that year. Amounts presented in the table above are included in Other income (expense), net in CenterPoint Energy’s Condensed Statements of Consolidated Income, net of regulatory deferrals.

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(19) Leases

In 2021, Houston Electric entered into a temporary short-term lease and a long-term lease, each for mobile generation. The short-term lease agreement allows Houston Electric to take delivery of TEEEF assets on a short-term basis with an initial term ending on September 30, 2022 and extended until December 31, 2022. Per Houston Electric’s short term lease accounting policy election, a ROU asset and lease liability are not reflected on Houston Electric’s Condensed Consolidated Balance Sheets. Expenses associated with the short-term lease, including carrying costs, are deferred to a regulatory asset and totaled $90 million and $20 million as of September 30, 2022 and December 31, 2021, respectively.

Houston Electric took delivery of an additional 32 MW and 160 MW of TEEEF under the long-term lease during the three and nine months ended September 30, 2022, respectively, and remitted cash payments under the lease of $47 million and $218 million, respectively. These assets were previously available under the short-term lease agreement. Houston Electric derecognized the finance lease liability when the extinguishment criteria in Topic 405 - Liabilities was achieved. Per the terms of the agreement, lease payments are due and made in full by Houston Electric upon taking possession of the asset, relieving substantially all of the associated finance lease liability at that time. The remaining finance lease liability associated with the commenced long-term TEEEF agreement was not significant as of September 30, 2022 and December 31, 2021 and relates to removal costs that will be incurred at the end of the lease term. The long-term lease agreement includes up to 505 MW of TEEEF of which 285 MW and 125 MW was delivered as of September 30, 2022 and December 31, 2021, respectively, triggering lease commencement at delivery, and has an initial term ending in 2029 for all TEEEF leases. As of September 30, 2022, Houston Electric has secured a first lien on all the generation equipment long-term leases and no amount of the payments made by Houston Electric under long-term leases were held in escrow. Expenses associated with the long-term lease, including carrying costs, are deferred to a regulatory asset and totaled $41 million and $1 million as of September 30, 2022 and December 31, 2021, respectively. The long-term lease agreement also contains a termination clause that can be exercised in the event of material adverse regulatory actions. For further discussion of the regulatory impacts, see Note 6.

The components of lease cost, included in Operation and maintenance expense on the Registrants’ respective Condensed Statements of Consolidated Income, are as follows:


	Three Months Ended September 30, 2022						Three Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	2	$	—	$	—	$	2	$	—	$	1
Short-term lease cost	39		39		1		54		54		—
Variable lease cost	—		—		—		—		—		—
Total lease cost (1)	$	41	$	39	$	1	$	56	$	54	$	1

	Nine Months Ended September 30, 2022						Nine Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	4	$	—	$	1	$	6	$	—	$	3
Short-term lease cost	123		122		1		89		89		—
Variable lease cost	—		—		—		—		—		—
Total lease cost (1)	$	127	$	122	$	2	$	95	$	89	$	3

(1) CenterPoint Energy and Houston Electric defer finance lease costs for TEEEF to Regulatory assets for recovery rather than recognizing Depreciation and Amortization in the Condensed Statements of Consolidated Income.

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The components of lease income were as follows:


	Three Months Ended September 30, 2022						Three Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease income	$	1	$	1	$	1	$	1	$	1	$	1
Variable lease income	—		—		—		—		—		—
Total lease income	$	1	$	1	$	1	$	1	$	1	$	1

	Nine Months Ended September 30, 2022						Nine Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease income	$	4	$	1	$	2	$	4	$	1	$	2
Variable lease income	1		—		—		1		—		—
Total lease income	$	5	$	1	$	2	$	5	$	1	$	2

Supplemental balance sheet information related to leases was as follows:


	September 30, 2022									December 31, 2021
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	15		$	—		$	6		$	22		$	1		$	12
Finance ROU assets (2)	367			367			—			179			179			—
Total leased assets	$	382		$	367		$	6		$	201		$	180		$	12

Liabilities:
Current operating lease liability (3)	$	5		$	—		$	2		$	6		$	1		$	2
Non-current operating lease liability (4)	10			—			4			17			—			11
Total leased liabilities (5)	$	15		$	—		$	6		$	23		$	1		$	13

Weighted-average remaining lease term (in years) - operating leases	5			5.4			4.1			6.2			4.1			6.5
Weighted-average discount rate - operating leases	3.16		%	3.50		%	3.55		%	3.10		%	2.86		%	3.20		%
Weighted-average remaining lease term (in years) - finance leases	6.8			6.8			—			7.5			7.5			—
Weighted-average discount rate - finance leases	2.73		%	2.73		%	—			2.21		%	2.21		%	—

(1)Reported within Other assets in the Registrants’ respective Condensed Consolidated Balance Sheets.

(2)Reported within Property, Plant and Equipment in the Registrants’ respective Condensed Consolidated Balance Sheets. Finance lease assets are recorded net of accumulated amortization.

(3)Reported within Current other liabilities in the Registrants’ respective Condensed Consolidated Balance Sheets.

(4)Reported within Other liabilities in the Registrants’ respective Condensed Consolidated Balance Sheets.

(5)Finance lease liabilities were not significant as of September 30, 2022 or December 31, 2021 and are reported within Other long-term debt in the Registrants’ respective Condensed Consolidated Balance Sheets when applicable.

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As of September 30, 2022, finance lease liabilities were not significant to the Registrants. As of September 30, 2022, maturities of operating lease liabilities were as follows:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remainder of 2022	$	2	$	—	$	1
2023	5		—		2
2024	4		—		2
2025	2		—		1
2026	2		—		1
2027 and beyond	2		—		—
Total lease payments	17		—		7
Less: Interest	2		—		1
Present value of lease liabilities	$	15	$	—	$	6

As of September 30, 2022, future minimum finance lease payments were not significant to the Registrants, exclusive of approximately $271 million of legally-binding undiscounted minimum lease payments for finance leases for approximately 220 MW of TEEEF leases signed but not yet commenced. As of September 30, 2022, maturities of undiscounted operating lease payments to be received are as follows:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remainder of 2022	$	1	$	—	$	1
2023	7		1		4
2024	7		1		4
2025	7		1		4
2026	7		—		4
2027	7		—		4
2028 and beyond	160		—		156
Total lease payments to be received	$	196	$	3	$	177

Other information related to leases is as follows:


	Three Months Ended September 30, 2022						Three Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	$	1	$	—	$	—	$	2	$	—	$	1
Financing cash flows from finance leases included in the measurement of lease liabilities	47		47		—		—		—		—

	Nine Months Ended September 30, 2022						Nine Months Ended September 30, 2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	$	4	$	—	$	1	$	5	$	—	$	3
Financing cash flows from finance leases included in the measurement of lease liabilities	218		218		—		—		—		—

See Note 16 for information on ROU assets obtained in exchange for operating lease liabilities.

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Item 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS OF CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

The following combined discussion and analysis should be read in combination with the Interim Condensed Financial Statements contained in this combined Form 10-Q and the Registrants’ combined 2021 Form 10-K. When discussing CenterPoint Energy’s consolidated financial information, it includes the results of Houston Electric and CERC, which, along with CenterPoint Energy, are collectively referred to as the Registrants. Where appropriate, information relating to a specific Registrant has been segregated and labeled as such. In this combined Form 10-Q, the terms “our,” “we” and “us” are used as abbreviated references to CenterPoint Energy, Inc. together with its consolidated subsidiaries. No Registrant makes any representations as to the information related solely to CenterPoint Energy or the subsidiaries of CenterPoint Energy other than itself.

RECENT EVENTS

Regulatory Proceedings. The commissioners of the MPUC held deliberations in August 2022 regarding CERC’s natural gas cost prudency review case related to the February 2021 Winter Storm Event. As a result, the MPUC disallowed recovery of approximately $36 million of jurisdictional gas costs incurred during the event (or about 8.7% of the total of such costs incurred by CERC) and CERC’s regulatory asset balance as of September 30, 2022 was reduced to reflect the disallowance. For further information, see Note 6 to the Interim Condensed Financial Statements. For information related to our pending and completed regulatory proceedings to date in 2022, see “—Liquidity and Capital Resources —Regulatory Matters” below.

Debt Transactions. During the nine months ended September 30, 2022, Houston Electric issued $1,600 million and CERC issued or borrowed $1,000 million in new debt, excluding the debt exchanges discussed below. CenterPoint Energy repaid or redeemed a combined $1,330 million of debt, including CERC’s redemption of $425 million of debt, but excluding scheduled principal payments on Securitization Bonds. In October 2022, Houston Electric redeemed an additional $200 million of debt. For information about debt transactions to date in 2022, see Note 11 to the Interim Condensed Financial Statements.

Debt Exchange. On September 6, 2022, CERC Corp. and VUH announced that CERC Corp. had commenced an offer to eligible holders to exchange any and all outstanding 6.10% senior notes issued by Vectren Utility Holdings, Inc. (predecessor of VUH) for (1) up to $75 million aggregate principal amount of new senior notes issued by CERC Corp. and (2) cash. On October 5, 2022, in connection with the settlement of the exchange offer, CERC Corp. issued $75 million aggregate principal amount of 6.10% senior notes due 2035 in exchange for all outstanding VUH senior notes. For additional information, see Note 11 to the Interim Condensed Financial Statements.

As a part of the Restructuring, on May 27, 2022, CERC Corp. and VUH completed an exchange with holders of VUH PPNs whereby CERC Corp. issued new senior notes with an aggregate principal amount of $302 million in return for all of their outstanding VUH PPNs with an aggregate principal amount of $302 million. For additional information, see Note 11 to the Interim Condensed Financial Statements.

Restructuring. CenterPoint Energy completed the Restructuring on June 30, 2022 whereby the equity interests in Indiana Gas and VEDO, each of which were acquired in its acquisition of Vectren on February 1, 2019, were transferred from VUH to CERC Corp. As a result, Indiana Gas and VEDO became wholly owned subsidiaries of CERC Corp. to better align CenterPoint Energy’s organizational structure with management and financial reporting and to fund future capital investments more efficiently. For additional information, see Note 1 to the Interim Condensed Financial Statements.

VUH Credit Facility. On June 30, 2022, in connection with the Restructuring, VUH repaid in full all outstanding indebtedness and terminated all remaining commitments and other obligations under its $400 million amended and restated credit agreement dated as of February 4, 2021. For additional information, see Note 11 to the Interim Condensed Financial Statements.

Sale of Energy Transfer Equity Securities. During the nine months ended September 30, 2022, CenterPoint Energy sold its remaining Energy Transfer Common Units and Energy Transfer Series G Preferred Units for net proceeds of $702 million. For more information, see Note 10 to the Interim Condensed Financial Statements.

Sale of Natural Gas Businesses. On January 10, 2022, CERC Corp. completed the sale of its Arkansas and Oklahoma Natural Gas businesses. For additional information regarding discontinued operations and divestitures, see Note 3 to the Interim Condensed Financial Statements.

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CENTERPOINT ENERGY CONSOLIDATED RESULTS OF OPERATIONS

For information regarding factors that may affect the future results of our consolidated operations, please read “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.

Income available to common shareholders for the three and nine months ended September 30, 2022 and 2021 was as follows:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022		2021		Favorable (Unfavorable)		2022		2021		Favorable (Unfavorable)
	(in millions)
Electric	$	234	$	185	$	49	$	489	$	385	$	104
Natural Gas	(10)		5		(15)		416		308		108
Total Utility Operations	224		190		34		905		693		212

Corporate & Other (1)	(35)		(63)		28		(19)		(145)		126
Discontinued Operations	—		68		(68)		—		202		(202)
Total CenterPoint Energy	$	189	$	195	$	(6)	$	886	$	750	$	136

(1)Includes energy performance contracting and sustainable infrastructure services through Energy Systems Group, unallocated corporate costs, interest income and interest expense, intercompany eliminations and the reduction of income allocated to preferred shareholders.

Three months ended September 30, 2022 compared to three months ended September 30, 2021

Income available to common shareholders decreased $6 million primarily due to the following items:

•an increase in net income of $49 million for the Electric reportable segment, as further discussed below;

•a decrease in net income of $15 million for the Natural Gas reportable segment, as further discussed below;

•an increase in income available to common shareholders of $28 million for Corporate and Other, partially driven by a $28 million pre-tax payment related to the impact of Board-implemented governance changes announced in July 2021 and a decrease in income allocated to preferred shareholders of $10 million, primarily due to the conversion of the Series B Preferred Stock to Common Stock during 2021; and

•a decrease in income of $68 million from discontinued operations, discussed further in Note 3 to the Interim Condensed Financial Statements.

Nine months ended September 30, 2022 compared to nine months ended September 30, 2021

Income available to common shareholders increased $136 million primarily due to the following items:

•an increase in net income of $104 million for the Electric reportable segment, as further discussed below;

•an increase in net income of $108 million for the Natural Gas reportable segment, as further discussed below;

•an increase in income available to common shareholders of $126 million for Corporate and Other, primarily due to a $28 million pre-tax payment related to the impact of Board-implemented governance changes announced in July 2021, the net gain of $86 million on Energy Transfer equity securities discussed further in Note 10 to the Interim Condensed Financial Statements, and a decrease in income allocated to preferred shareholders of $45 million, primarily due to the conversion of the Series B Preferred Stock to Common Stock during 2021; and

•a decrease in income of $202 million from discontinued operations, discussed further in Note 3 to the Interim Condensed Financial Statements.

Income Tax Expense. For a discussion of effective tax rate per period, see Note 12 to the Interim Condensed Financial Statements.

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CENTERPOINT ENERGY’S RESULTS OF OPERATIONS BY REPORTABLE SEGMENT

CenterPoint Energy’s CODM views net income as the measure of profit or loss for the reportable segments. Segment results include inter-segment interest income and expense, which may result in inter-segment profit and loss. During the nine months ended September 30, 2022, CenterPoint Energy sold certain assets previously owned by entities within Corporate and Other to businesses within the Electric and Natural Gas reportable segments. Prior year amounts were reclassified as a result of the transaction in the nine months ended September 30, 2022.

The following discussion of results of operations by reportable segment concentrates on CenterPoint Energy’s Utility Operations, conducted through two reportable segments, Electric and Natural Gas.

Electric (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of the Electric reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Electric Generation, Transmission and Distribution Businesses,” “— Risk Factors Affecting Our Businesses” and “— General Risk Factors Affecting Our Businesses” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.

The following table provides summary data of the Electric reportable segment:


	Three Months Ended September 30,									Nine Months Ended September 30,
	2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)
	(in millions, except operating statistics)
Revenues	$	1,146		$	1,056		$	90		$	3,092		$	2,823		$	269
Expenses:
Utility natural gas, fuel and purchased power	65			53			(12)			162			142			(20)
Operation and maintenance	465			440			(25)			1,351			1,280			(71)
Depreciation and amortization	207			216			9			604			584			(20)
Taxes other than income taxes	67			69			2			207			205			(2)

Total expenses	804			778			(26)			2,324			2,211			(113)
Operating Income	342			278			64			768			612			156
Other Income (Expense):
Interest expense and other finance charges	(58)			(57)			(1)			(174)			(171)			(3)

Other income, net	9			7			2			21			19			2
Income Before Income Taxes	293			228			65			615			460			155
Income tax expense	59			43			(16)			126			75			(51)
Net Income	$	234		$	185		$	49		$	489		$	385		$	104
Throughput (in GWh):
Residential	11,970			11,174			7		%	28,319			25,567			11		%
Total	30,330			31,178			(3)		%	82,755			79,305			4		%
Weather (percentage of 10-year average for service area):
Cooling degree days	105		%	101		%	4		%	110		%	102		%	8		%
Heating degree days	200		%	100		%	100		%	121		%	105		%	16		%
Number of metered customers at end of period:
Residential	2,527,383			2,480,292			2		%	2,527,383			2,480,292			2		%
Total	2,850,910			2,800,548			2		%	2,850,910			2,800,548			2		%

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The following table provides variance explanations by major income statement caption for the Electric reportable segment:


	Favorable (Unfavorable)
	Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021
	(in millions)
Revenues
Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers, partially offset in operation and maintenance	$	40	$	115
Weather, efficiency improvements and other usage impacts	11		53
Refund of protected and unprotected EDIT, offset in income tax expense	11		28
Customer growth	9		22
Cost of fuel and purchased power, offset in utility natural gas, fuel and purchased power below	13		21
Customer rates	13		20
Energy efficiency and pass-through offset in operation and maintenance	19		15
Miscellaneous revenues, primarily related to off-system sales	(1)		9
Bond Companies equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods	(1)		2
Impacts from increased peak demand in 2021, collected in rates in 2022	—		2
Bond Companies, offset in other line items	(24)		(18)
Total	$	90	$	269
Utility natural gas, fuel and purchased power
Cost of purchased power, offset in revenues above	$	9	$	16
Cost of fuel, including coal, natural gas, and fuel oil, offset in revenues above	(21)		(36)
Total	$	(12)	$	(20)
Operation and maintenance
Transmission costs billed by transmission providers, offset in revenues	(18)		$	(61)

All other operation and maintenance expense, including insurance and bad debt	2		(10)
Materials and supplies, including variable production costs and fuel	(3)		(9)
Contract services	—		(8)
Bond Companies, offset in other line items	1		2
Energy efficiency and pass-through offset in revenues, including NOx emission credits	(18)		(13)

Labor and benefits	6		6
Support services, primarily information technology cost	5		22
Total	$	(25)	$	(71)
Depreciation and amortization
Bond Companies, offset in other line items	$	21	$	10
Ongoing additions to plant-in-service	(12)		(30)
Total	$	9	$	(20)
Taxes other than income taxes
Franchise fees and other taxes	$	2	$	5
Incremental capital projects placed in service, net of updated property tax rates	—		(7)
Total	$	2	$	(2)
Interest expense and other finance charges
Bond Companies, offset in other line items	$	2	$	6
Incremental borrowings to fund capital expenditures and interest rates	(3)		(9)
Total	$	(1)	$	(3)
Other income, net
Other non-operating income	$	2	$	2


Total	$	2	$	2

Income Tax Expense. For a discussion of effective tax rate per period by Registrant, see Note 12 to the Interim Condensed Financial Statements.

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Natural Gas (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of CenterPoint Energy’s Natural Gas reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas' Business,” “— Risk Factors Affecting Our Businesses” and “— General Risk Factors Affecting Our Businesses” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.

The following table provides summary data of CenterPoint Energy’s Natural Gas reportable segment:


	Three Months Ended September 30,									Nine Months Ended September 30,
	2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)
	(in millions, except operating statistics)
Revenues	$	692		$	619		$	73		$	3,334		$	3,022		$	312
Expenses:
Utility natural gas, fuel and purchased power	284			170			(114)			1,698			1,274			(424)
Non-utility cost of revenues, including natural gas	1			3			2			3			15			12
Operation and maintenance	199			225			26			654			715			61
Depreciation and amortization	118			135			17			347			392			45
Taxes other than income taxes	51			53			2			189			184			(5)
Total expenses	653			586			(67)			2,891			2,580			(311)
Operating Income	39			33			6			443			442			1
Other Income (Expense):
Gain on sale	—			8			(8)			303			8			295
Interest expense and other finance charges	(34)			(34)			—			(97)			(101)			4

Other income (expense), net	—			(1)			1			(10)			1			(11)
Income Before Income Taxes	5			6			(1)			639			350			289
Income tax expense	15			1			(14)			223			42			(181)
Net Income (Loss)	$	(10)		$	5		$	(15)		$	416		$	308		$	108



Throughput (in Bcf):
Residential	15			17			(12)		%	166			175			(5)		%
Commercial and Industrial	81			79			3		%	307			312			(2)		%
Total	96			96			—		%	473			487			(3)		%
Weather (percentage of 10-year average for service area):
Heating degree days	85		%	39		%	46		%	108		%	99		%	9		%
Number of metered customers at end of period:
Residential	3,920,848			4,332,079			(9)		%	3,920,848			4,332,079			(9)		%
Commercial and Industrial	296,144			348,443			(15)		%	296,144			348,443			(15)		%
Total	4,216,992			4,680,522			(10)		%	4,216,992			4,680,522			(10)		%

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The following table provides variance explanations by major income statement caption for the Natural Gas reportable segment:


	Favorable (Unfavorable)
	Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021
	(in millions)
Revenues
Cost of natural gas, offset in utility natural gas, fuel and purchased power below	$	132	$	538
Customer rates and impact of the change in rate design, exclusive of the TCJA impact	(3)		53
Gross receipts tax, offset in taxes other than income taxes	(1)		13
Customer growth	5		10
Weather and usage	15		10
Refund of protected and unprotected EDIT, offset in income tax expense	1		6
Non-volumetric and miscellaneous revenue	(3)		6

Energy efficiency, offset in operation and maintenance	(3)		(5)
Other, primarily non-utility revenues	(8)		(23)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	(62)		(296)
Total	$	73	$	312
Utility natural gas, fuel and purchased power
Cost of natural gas, offset in revenues above	$	(132)	$	(538)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	18		114


Total	$	(114)	$	(424)
Non-utility costs of revenues, including natural gas
Other, primarily non-utility cost of revenues	$	2	$	12
Total	$	2	$	12
Operation and maintenance

Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	32	$	93
Labor and benefits	10		7
Energy efficiency, offset in revenues	3		5
Contract services	(5)		(5)
Other operation and maintenance expenses, including material and supplies and bad debt	(14)		(39)
Total	$	26	$	61
Depreciation and amortization
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	20	$	50
Lower depreciation rates in Indiana from recent rate order	5		15
Incremental capital projects placed in service	(8)		(20)

Total	$	17	$	45
Taxes other than income taxes
Gross receipts tax, offset in revenues	$	1	$	(13)
Incremental capital projects placed in service	(3)		(8)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	4		16
Total	$	2	$	(5)
Gain on sale
Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	(8)	$	295
Total	$	(8)	$	295
Interest expense and other finance charges
Impacts of February 2021 Winter Storm costs securitization	$	4	$	6
AFUDC and impacts of regulatory deferrals	6		8
Reduction of long term debt, net of issuances	(10)		(10)
Total	$	—	$	4



Other income (expense), net
Increase in Equity AFUDC	$	2	$	3
Increase to non-service benefit cost	(3)		(16)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	2		2
Total	$	1	$	(11)

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Income Tax Expense. For a discussion of effective tax rate per period by Registrant, see Note 12 to the Interim Condensed Financial Statements.

HOUSTON ELECTRIC’S MANAGEMENT’S NARRATIVE ANALYSIS

OF CONSOLIDATED RESULTS OF OPERATIONS

Houston Electric’s CODM views net income as the measure of profit or loss for its reportable segment. Houston Electric consists of a single reportable segment. Houston Electric’s results of operations are affected by seasonal fluctuations in the demand for electricity. Houston Electric’s results of operations are also affected by, among other things, the actions of various governmental authorities having jurisdiction over rates Houston Electric charges, debt service costs, income tax expense, Houston Electric’s ability to collect receivables from REPs and Houston Electric’s ability to recover its regulatory assets. For more information regarding factors that may affect the future results of operations of Houston Electric’s business, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Electric Generation, Transmission and Distribution Businesses,” “— Risk Factors Affecting Our Businesses” and “— General Risk Factors Affecting Our Businesses” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.


	Three Months Ended September 30,									Nine Months Ended September 30,
	2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)
	(in millions, except operating statistics)
Revenues:
TDU	$	879		$	794		$	85		$	2,394		$	2,159		$	235
Bond Companies	56			80			(24)			168			185			(17)
Total revenues	935			874			61			2,562			2,344			218
Expenses:
Operation and maintenance, excluding Bond Companies	393			394			1			1,190			1,154			(36)
Depreciation and amortization, excluding Bond Companies	123			108			(15)			357			320			(37)
Taxes other than income taxes	65			64			(1)			196			192			(4)
Bond Companies	54			76			22			157			169			12
Total expenses	635			642			7			1,900			1,835			(65)
Operating Income	300			232			68			662			509			153
Other Income (Expense)
Interest expense and other finance charges	(50)			(46)			(4)			(148)			(138)			(10)
Interest expense on Securitization Bonds	(3)			(5)			2			(11)			(16)			5


Other income, net	5			4			1			13			12			1
Income Before Income Taxes	252			185			67			516			367			149
Income tax expense	52			34			(18)			108			60			(48)
Net Income	$	200		$	151		$	49		$	408		$	307		$	101
Throughput (in GWh):
Residential	11,525			10,723			7		%	27,223			24,448			11		%
Total	28,928			29,318			(1)		%	78,565			74,453			6		%
Weather (percentage of 10-year average for service area):
Cooling degree days	105		%	101		%	4		%	111		%	103		%	8		%
Heating degree days	—		%	—		%	—		%	124		%	105		%	19		%
Number of metered customers at end of period:
Residential	2,392,107			2,345,920			2		%	2,392,107			2,345,920			2		%
Total	2,696,366			2,646,955			2		%	2,696,366			2,646,955			2		%

The following table provides variance explanations by major income statement caption for Houston Electric:


	Favorable (Unfavorable)
	Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021
	(in millions)
Revenues
Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers	$	41	$	116
Weather impacts and other usage	14		56
Refund of protected and unprotected EDIT, offset in income tax expense	11		28
Customer growth	8		21

Customer rates	12		12
Miscellaneous revenues, primarily related to right-of-way revenues	3		5
Equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods	(1)		2
Impacts from increased peak demand in 2021, collected in rates in 2022	—		2
Energy efficiency, offset in operation and maintenance	(3)		(6)
Bond Companies, offset in other line items	(24)		(18)

Total	$	61	$	218
Operation and maintenance, excluding Bond Companies
Transmission costs billed by transmission providers, offset in revenues	$	(18)	$	(61)
Materials and Supplies, including fuel	(4)		(7)
Contract services	—		(6)
Other operation and maintenance expense, including insurance	7		1
Energy efficiency, offset in revenues	3		6


Labor and benefits	6		8
Support services, primarily information technology cost	7		23
Total	$	1	$	(36)
Depreciation and amortization, excluding Bond Companies
Ongoing additions to plant-in-service	$	(15)	$	(37)
Total	$	(15)	$	(37)
Taxes other than income taxes
Franchise fees and other taxes	$	(1)	$	3
Incremental capital projects placed in service, net of updated property tax rates	—		(7)
Total	$	(1)	$	(4)
Bond Companies expense
Operations and maintenance and depreciation expense, offset in other line items	$	22	$	12
	$	22	$	12
Interest expense and other finance charges
Incremental borrowings to fund capital expenditures and changes in interest rates	$	(4)	$	(10)
Total	$	(4)	$	(10)




Interest expense on Securitization Bonds
Lower outstanding principal balance, offset in other line items	$	2	$	5
Total	$	2	$	5
Other income, net
Other non-operating income	$	1	$	1


Total	$	1	$	1

Income Tax Expense. For a discussion of effective tax rate per period, see Note 12 to the Interim Condensed Financial Statements.

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CERC’S MANAGEMENT’S NARRATIVE ANALYSIS OF CONSOLIDATED RESULTS OF OPERATIONS

CERC’s CODM views net income as the measure of profit or loss for its reportable segment. CERC’s results of operations are affected by seasonal fluctuations in the demand for natural gas. CERC’s results of operations are also affected by, among other things, the actions of various federal, state and local governmental authorities having jurisdiction over rates CERC charges, debt service costs and income tax expense, CERC’s ability to collect receivables from customers and CERC’s ability to recover its regulatory assets. As a result of the Restructuring further discussed in Note 1 to the Interim Condensed Financial Statements, prior year amounts have been recast. For more information regarding factors that may affect the future results of operations for CERC’s business, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas’ Business,” “— Risk Factors Affecting Our Businesses” and “— General Risk Factors Affecting Our Businesses” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.


	Three Months Ended September 30,									Nine Months Ended September 30,
	2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)
	(in millions, except operating statistics)
Revenues	$	672		$	609		$	63		$	3,232		$	2,925		$	307
Expenses:
Utility natural gas, fuel and purchased power	276			173			(103)			1,660			1,230			(430)
Non-utility cost of revenues, including natural gas	1			4			3			3			16			13
Operation and maintenance	190			223			33			630			709			79
Depreciation and amortization	113			127			14			333			363			30
Taxes other than income taxes	50			53			3			185			182			(3)
Total expenses	630			580			(50)			2,811			2,500			(311)
Operating Income	42			29			13			421			425			(4)
Other Income (Expense):
Gain on sale	—			11			(11)			557			11			546
Interest expense and other finance charges	(32)			(32)			—			(91)			(96)			5

Other income (expense), net	—			(2)			2			(11)			—			(11)
Income Before Income Taxes	10			6			4			876			340			536
Income tax expense	17			1			(16)			220			40			(180)


Net Income (Loss)	$	(7)		$	5		$	(12)		$	656		$	300		$	356
Throughput (in Bcf):
Residential	14			16			(13)		%	161			170			(5)		%
Commercial and Industrial	74			72			3		%	281			289			(3)		%
Total	88			88			—		%	442			459			(4)		%
Weather (percentage of 10-year average for service area):
Heating degree days	85		%	40		%	45		%	108		%	99		%	9		%
Number of metered customers at end of period:
Residential	3,817,553			4,229,228			(10)		%	3,817,553			4,229,228			(10)		%
Commercial and Industrial	285,576			330,795			(14)		%	285,576			330,795			(14)		%
Total	4,103,129			4,560,023			(10)		%	4,103,129			4,560,023			(10)		%

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The following table provides variance explanations by major income statement caption for CERC:


	Favorable (Unfavorable)
	Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021
	(in millions)
Revenues
Cost of natural gas, offset in utility natural gas, fuel and purchased power below	$	121	$	544
Customer rates and impact of the change in rate design, exclusive of the TCJA impact	(3)		39
Gross receipts tax, offset in taxes other than income taxes	(1)		13
Customer growth	5		10
Weather and usage	16		10
Refund of protected and unprotected EDIT, offset in income tax expense	1		6
Non-volumetric and miscellaneous revenue	(5)		3
Energy efficiency, offset in operation and maintenance	(1)		1

Other, primarily non-utility revenues	(8)		(23)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	(62)		(296)
Total	$	63	$	307
Utility natural gas, fuel and purchased power
Cost of natural gas, offset in revenues above	$	(121)	$	(544)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	18		114


Total	$	(103)	$	(430)
Non-utility costs of revenues, including natural gas
Other, primarily non-utility cost of revenues	$	3	$	13
Total	$	3	$	13
Operation and maintenance
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	32	$	93
Labor and benefits	10		8
Energy efficiency, offset in revenues	1		(1)
Contract services	(3)		(3)
Other operating and maintenance expense, including materials and supplies and insurance	(7)		(18)



Total	$	33	$	79
Depreciation and amortization
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	20	$	50
Indiana lower depreciation rates from recent rate order	2		12
Incremental capital projects placed in service	(8)		(32)

Total	$	14	$	30
Taxes other than income taxes
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	4	$	16
Incremental capital projects placed in service	(2)		(6)
Gross receipts tax, offset in revenues	1		(13)
Total	$	3	$	(3)
Gain on sale
Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	(11)	$	546
Total	$	(11)	$	546
Interest expense and other finance charges
Impacts of February 2021 Winter Storm costs securitization	$	4	$	6
AFUDC and impacts of regulatory deferrals	5		8
Reduction of long term debt, net of issuances	(9)		(9)
Total	$	—	$	5



Other income (expense), net
Increase in Equity AFUDC	$	2	$	3
Increase to non-service benefit cost	(2)		(16)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	2		2
Total	$	2	$	(11)

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Income Tax Expense. For a discussion of effective tax rate per period, see Note 12 to the Interim Condensed Financial Statements.

CERTAIN FACTORS AFFECTING FUTURE EARNINGS

For information on other developments, factors and trends that may have an impact on the Registrants’ future earnings, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Certain Factors Affecting Future Earnings” in Item 7 of Part II and “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K, in Item 1A of Part II of this combined Form 10-Q and “Cautionary Statement Regarding Forward-Looking Information” in this combined Form 10-Q.

LIQUIDITY AND CAPITAL RESOURCES

Historical Cash Flows

As a result of the Restructuring further discussed in Note 1 to the Interim Condensed Financial Statements, prior year amounts for CERC have been recast. The following table summarizes the net cash provided by (used in) operating, investing and financing activities during the nine months ended September 30, 2022 and 2021:


	Nine Months Ended September 30,
	2022						2021
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash provided by (used in):
Operating activities	$	1,325	$	545	$	753	$	(517)	$	497	$	(1,359)
Investing activities	(229)		(2,053)		921		(2,104)		(1,104)		(847)
Financing activities	(1,220)		1,402		(1,688)		2,610		576		2,201

Operating Activities. The following items contributed to increased (decreased) net cash provided by operating activities for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Changes in net income after adjusting for non-cash items	$	(374)	$	164	$	(44)
Changes in working capital	(563)		(245)		(207)
Change in net regulatory assets and liabilities (1)	2,457		150		2,334
Change in equity in earnings of unconsolidated affiliates (2)	258		—		—
Change in distributions from unconsolidated affiliates (2)	(116)		—		—

Lower pension contribution	53		—		—
Other	127		(21)		29
	$	1,842	$	48	$	2,112

(1)The change in net regulatory assets and liabilities at CenterPoint Energy and CERC is primarily due to the extraordinary natural gas costs associated with the February 2021 Winter Storm Event. See Note 6 to the Interim Condensed Financial Statements for more information on the February 2021 Winter Storm Event.

(2)In September 2021, CenterPoint Energy’s equity investment in Enable met the held for sale criteria and is reflected as discontinued operations on CenterPoint Energy’s Condensed Statements of Consolidated Income. For further information, see Note 3 to the Interim Condensed Financial Statements.

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Investing Activities. The following items contributed to (increased) decreased net cash used in investing activities for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Proceeds from the sale of equity securities	$	702	$	—	$	—

Capital expenditures	(931)		(619)		(361)
Net change in notes receivable from affiliated companies	—		(360)		25


Proceeds from divestitures	2,053		—		2,053


Other	51		30		51
	$	1,875	$	(949)	$	1,768

Financing Activities. The following items contributed to (increased) decreased net cash used in financing activities for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Net changes in commercial paper outstanding	$	(2,216)	$	—	$	(662)


Net changes in long-term debt outstanding, excluding commercial paper	(1,899)		589		(1,272)


Net changes in debt issuance costs	12		(3)		(1)
Net changes in short-term borrowings	484		—		484

Payment of obligation for finance lease	(218)		(218)		—
Increased payment of common stock dividends	(50)		—		—
Decreased payment of preferred stock dividends	58		—		—
Net change in notes payable from affiliated companies	—		(544)		(1,720)
Contribution from parent	—		1,143		125
Dividend to parent	—		(141)		(844)


Other	(1)		—		1
	$	(3,830)	$	826	$	(3,889)

Future Sources and Uses of Cash

The liquidity and capital requirements of the Registrants are affected primarily by results of operations, capital expenditures, debt service requirements, tax payments, working capital needs and various regulatory actions. Capital expenditures are expected to be used for investment in infrastructure. These capital expenditures are anticipated to maintain reliability and safety, increase resiliency and expand our systems through value-added projects. In addition to dividend payments on CenterPoint Energy’s Series A Preferred Stock and Common Stock and interest payments on debt, the Registrants’ principal anticipated cash requirements for the remaining three months of 2022 include the following:


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Estimated capital expenditures	$	1,088	$	552	$	413
Scheduled principal payments on Securitization Bonds	76		76		—
Minimum contributions to pension plans and other post-retirement plans	3		—		1
Finance lease for TEEEF	271		271		—

The Registrants expect that anticipated cash needs for the remaining three months of 2022 will be met with borrowings under their credit facilities, proceeds from the issuance of long-term debt, term loans, anticipated proceeds from the Texas Public Financing Authority customer rate relief bonds for recovery of the gas cost incurred in Texas during the February 2021 Winter Storm Event, anticipated cash flows from operations, and, with respect to CenterPoint Energy and CERC, proceeds from commercial paper. Discretionary financing or refinancing may result in the issuance of debt securities of the Registrants in

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the capital markets or the arrangement of additional credit facilities or term bank loans. Issuances of debt in the capital markets, funds raised in the commercial paper markets and additional credit facilities may not, however, be available on acceptable terms.

Capital Expenditures Update. CenterPoint Energy announced in November 2022 an increase of $2.3 billion to its 10-year capital plan, concluding in 2030, which now totals nearly $43 billion.

Off-Balance Sheet Arrangements

Other than Houston Electric’s general mortgage bonds issued as collateral for tax-exempt long-term debt of CenterPoint Energy as discussed in Note 11 and guarantees as discussed in Note 13(b) to the Interim Condensed Financial Statements, we have no off-balance sheet arrangements.

Regulatory Matters

February 2021 Winter Storm Event

For further information about the February 2021 Winter Storm Event, see Note 6 to the Interim Condensed Financial Statements.

Indiana Electric CPCN (CenterPoint Energy)

On February 9, 2021, Indiana Electric entered into a BTA with a subsidiary of Capital Dynamics. Under the agreement, Capital Dynamics, with its partner Tenaska, contracted to build a 300 MW solar array in Posey County, Indiana through a special purpose entity, Posey Solar. Upon completion of construction, Indiana Electric will acquire Posey Solar and its solar array assets for a fixed purchase price. On February 23, 2021, Indiana Electric filed a CPCN with the IURC seeking approval to purchase the project. Indiana Electric also sought approval for a 100 MW solar PPA with Clenera LLC in Warrick County, Indiana. The request accounted for increased cost of debt related to this PPA, which provides equivalent equity return to offset imputed debt during the 25 year life of the PPA. A hearing was conducted on June 21, 2021. On October 27, 2021, the IURC issued an order approving the CPCN, authorizing Indiana Electric to purchase the Posey solar project through a BTA and approved recovery of costs via a levelized rate over the anticipated 35-year life. The IURC also approved the Warrick County solar PPA but denied the request to preemptively offset imputed debt in the PPA cost. The Posey solar project is expected to be placed in service in 2024. Due to rising cost for the project, caused in part by supply chain issues in the energy industry, the rising costs of commodities and community feedback, we, along with Capital Dynamics, announced plans in January 2022 to downsize the Posey solar project to approximately 200 MW. Indiana Electric collaboratively agreed to the scope change and is currently working through contract negotiations, contingent on further IURC review and approval.

On June 17, 2021, Indiana Electric filed a CPCN with the IURC seeking approval to construct two natural gas combustion turbines to replace portions of its existing coal-fired generation fleet. A hearing was conducted on January 26 through 28, 2022, and on June 28, 2022 the IURC approved the CPCN. On July 18, 2022, the OUCC filed a petition for rehearing and reconsideration with the IURC of the approved turbine cost estimate and pipeline cost recovery issues and, as of July 29, 2022, three organizations, the OUCC, Citizens Action Coalition and Indiana Industrial Energy Consumers, had filed notices of appeal of the petition with the Indiana Court of Appeals. The IURC denied the OUCC’s request for rehearing and reconsideration on August 10, 2022. The OUCC, Citizens Action Coalition and Indiana Industrial Energy Consumers dismissed their appeal of the IURC order effective August 22, 2022. The estimated $334 million turbine facility is planned to be constructed at the current site of the A.B. Brown power plant in Posey County, Indiana and would provide a combined output of 460 MW. Indiana Electric received approval for depreciation expense and post in-service carrying costs to be deferred in a regulatory asset until the date Indiana South’s base rates include a return on and recovery of depreciation expense on the facility. A new approximately 23.5 mile pipeline will be constructed and operated by Texas Gas Transmission, LLC to supply natural gas to the turbine facility. FERC granted a certificate to construct the pipeline on October 20, 2022. Indiana Electric has issued a limited notice to proceed to its contractor and anticipates granting its contractor full notice to proceed to construct the turbines during the fourth quarter of 2022. The turbines are targeted to be operational by year end 2025. Recovery of the proposed natural gas combustion turbines and regulatory asset will be requested in the next Indiana Electric rate case expected in 2023.

On August 25, 2021, Indiana Electric filed with the IURC seeking approval to purchase 185 MW of solar power, under a 15-year PPA, from Oriden, which is developing a solar project in Vermillion County, Indiana, and 150 MW of solar power, under a 20-year PPA, from Origis, which is developing a solar project in Knox County, Indiana. On May 4, 2022, the IURC issued an order approving Indiana Electric to enter into both PPAs. In March 2022, when the results of the MISO interconnection study were completed, Origis advised Indiana Electric that the costs to construct the solar project in Knox County, Indiana had increased. The increase was largely driven by escalating commodity and supply chain costs impacting

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manufacturers worldwide. In August 2022, Indiana Electric and Origis entered into an amended PPA, which reiterated the terms contained in the 2021 PPA with certain modifications. On October 19, 2022, Indiana Electric filed with the IURC seeking approval of the amended PPA. The Oriden solar array is expected to be placed in service by the end of 2023 and the Origis solar array is expected to be placed in service by the end of 2024.

On July 5, 2022, Indiana Electric entered into a BTA to acquire a 130 MW solar array in Pike County, Indiana through a special purpose entity for a capped purchase price. A CPCN for the project was filed with the IURC on July 29, 2022. On September 21, 2022, an agreement in principle was reached resolving all the issues between Indiana Electric and OUCC. The Stipulation and Settlement agreement was filed on October 6, 2022 and a settlement hearing is scheduled for November 1, 2022. Pending approval, the project is expected to be placed in service by 2025.

For more information regarding uncertainties related to our solar projects, see Item 1A of Part II of this combined Form 10-Q and “ —Solar Panel Issues” below.

Culley Unit 3 Operations

In June 2022, F.B. Culley Unit 3, an Indiana Electric coal-fired electric generation unit with an installed generating capacity of 270 MW, experienced an operating issue relating to its boiler feed pump turbine, and it remains out of service. The current estimate of the costs to repair F.B. Culley Unit 3 is approximately $7 million to $9 million, which will largely be capital expenditures. CenterPoint Energy has located a replacement boiler feed pump turbine which is currently being refurbished by the original equipment manufacturer to ensure it is in good working order. Currently, F.B. Culley Unit 3 is expected to return to service in the first half of 2023 depending on the time it takes to refurbish, install and test operation of the replacement turbine and related materials. CenterPoint Energy is evaluating the applicability of insurance coverages. For the duration of the unplanned outage, CenterPoint Energy expects to meet its generation capacity needs from its other generation units and power purchase agreements.

Indiana Electric Securitization of Planned Generation Retirements (CenterPoint Energy)

The State of Indiana has enacted legislation, Senate Bill 386, that would enable CenterPoint Energy to request approval from the IURC to securitize the remaining book value and removal costs associated with generating facilities to be retired in the next twenty-four months. The Governor of Indiana signed the legislation on April 19, 2021. On May 10, 2022, CenterPoint Energy (Indiana Electric) filed with the IURC to securitize qualified costs associated with its planned retirements of coal generation facilities. Total qualified costs are estimated at $359 million, of which $350 million would be financed and $9 million are estimated total ongoing costs. A hearing was held before the IURC on September 7, 2022 and a final order is anticipated in early 2023.

Restructuring (CenterPoint Energy and CERC)

In July 2021, Indiana North and SIGECO filed petitions with the IURC for the approval of a new financial services agreement and the confirmation of Indiana North’s financing authority, and final orders were issued by the IURC on December 28, 2021. VEDO filed a similar application with the PUCO in September 2021 and the PUCO issued an order on January 26, 2022 adopting recommendations by PUCO staff. Both the IURC and PUCO approved the petitions. The orders allow the reissuance of existing debt of Indiana Gas and VEDO to CERC, to continue to amortize existing issuance expenses and discounts, and to treat any potential exchange fees as discounts to be amortized over the life of the debt. As a part of the Restructuring, on May 27, 2022, CERC Corp. and VUH completed an exchange with holders of VUH PPNs whereby CERC Corp. issued new senior notes with an aggregate principal amount of $302 million in return for all of their outstanding VUH PPNs with an aggregate principal amount of $302 million. Additionally, although not necessary to complete the Restructuring or the above mentioned exchange, on October 5, 2022, CERC Corp. closed a separate exchange offer for all outstanding VUH 6.10% senior notes. For further information on the debt exchanges, see Note 11 to the Interim Condensed Financial Statements. CenterPoint Energy completed the transfer of Indiana Gas and VEDO from VUH to CERC on June 30, 2022 to better align its organizational structure with management and financial reporting and to fund future capital investments more efficiently. See Note 1 to the Interim Condensed Financial Statements for further information.

Texas Legislation (CenterPoint Energy and Houston Electric)

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deferred costs and the applicable return as of December 31, 2021 under these lease agreements of approximately $200 million. The annual revenue increase requested for these lease agreements is approximately $57 million. A hearing was held on October 18 through 20, 2022. These TEEEF leases are expected to support resiliency in major weather events, as was the case during the restoration process for Hurricane Nicholas in 2021. For additional information, see Note 6 to the Interim Condensed Financial Statements.

In addition to these measures taken by Houston Electric to support system preparedness and reliability, Houston Electric has engaged in a customer outreach strategy, initially with the the City of Houston, on the first-of-its-kind long-term strategic power resilience initiative called “Resilient Now,” which now has grown to include several other cities and large industrial customers. The input received through this effort continues to help inform capital opportunities for Houston Electric, including relating to increased system resiliency, reliability and grid modernization, as well as to electric vehicles infrastructure.

Minnesota Base Rate Cases (CenterPoint Energy and CERC)

On November 1, 2021, CERC filed a general rate case with the MPUC seeking approval for a revenue increase of approximately $67 million with a projected test year ended December 31, 2022. The revenue increase is based upon a requested ROE of 10.2% and an overall rate of return of 7.06% on a total rate base of approximately $1.8 billion. CERC requested that an interim rate increase of approximately $52 million be implemented January 1, 2022 while the rate case is litigated. An alternative request was also filed on November 1, 2021. The alternative request proposed a final rate increase of $40 million that would be implemented in the rate case on January 1, 2022, and offered: an increase in rates for plant investment only using the overall rate of return approved in the prior rate case, an asymmetrical capital true-up, extension of the recovery of gas costs incurred to serve customers in February 2021 from the then current 27 month mechanism to 63 months, an income tax rider, continuation of the existing property tax rider and continued deferral of COVID-19 incremental costs along with additional adjustments. On December 30, 2021, the MPUC issued a written order denying the alternative request but extended the recovery for extraordinary gas costs to 63-months beginning on January 1, 2022. The MPUC also issued written orders on the general rate case filing which (1) accepted CERC’s rate-increase application with a time for final determination of September 1, 2022, (2) authorized the implementation of interim rates on January 1, 2022, of $42 million based on an overall rate of return of 6.46%, and (3) referred the case to the Office of Administrative Hearings for a contested case proceeding. On March 14, 2022, an Offer of Settlement was filed with the Office of Administrative Hearings which would resolve all issues in the rate case. The settlement provides for a general revenue increase of $48.5 million and overall rate of return of 6.65%. On August 18, 2022, the MPUC orally approved the settlement, and a written order was issued on September 23, 2022. After approval of CERC’s compliance filing, rate implementation is expected by January 1, 2023.

Minnesota Legislation (CenterPoint Energy and CERC)

The Natural Gas Innovation Act was passed by the Minnesota legislature in June 2021 with bipartisan support. This law establishes a regulatory framework to enable the state’s investor-owned natural gas utilities to provide customers with access to renewable energy resources and innovative technologies, with the goal of reducing greenhouse gas emissions and advancing the state’s clean energy future. Specifically, the Natural Gas Innovation Act allows a natural gas utility to submit an innovation plan for approval by the MPUC which could propose the use of renewable energy resources and innovative technologies such as:

•renewable natural gas (produces energy from organic materials such as wastewater, agricultural manure, food waste, agricultural or forest waste);

•renewable hydrogen gas (produces energy from water through electrolysis with renewable electricity such as solar);

•energy efficiency measures (avoids energy consumption in excess of the utility’s existing conservation programs); and

•innovative technologies (reduces or avoids greenhouse gas emissions using technologies such as carbon capture).

CERC expects to submit its first innovation plan to the MPUC in the first half of 2023. The maximum allowable cost for an innovation plan will start at 1.75% of the utility's revenue in the state and could increase to 4% by 2033, subject to review and approval by the MPUC.

Solar Panel Issues (CenterPoint Energy)

CenterPoint Energy’s current and future solar projects may be significantly impacted by delays and/or increased costs. The potential delays and inflationary cost pressures communicated from the developers of our solar projects are primarily due to (i) unavailability of solar panels and other uncertainties related to the pending DOC investigation on anti-dumping and countervailing duties petition filed by a domestic solar manufacturer, (ii) the December 2021 Uyghur Forced Labor Prevention Act on solar modules and other products manufactured in China's Xinjiang Uyghur Autonomous Region and (iii) persistent general global supply chain and labor availability issues. Preliminary findings from the DOC investigation, including potential tariff amounts, are expected to be released in November 2022, with a final decision expected in the first half of 2023. In June

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2022, President Biden authorized an executive order which would suspend anti-circumvention tariffs on solar panels for two years; however, the executive order could be subject to legal challenges and its effects remain uncertain. The resolution of these issues will determine what additional costs or delays our solar projects will be subject to. If any of these impacts result in cost increases for certain projects, such potential impacts are expected to result in the need for us to seek additional regulatory review and approvals. Additionally, significant changes to project costs and schedules as a result of these factors could impact the viability of the projects. For more information regarding potential delays, cancellations and supply chain disruptions, see “Item 1A. Risk Factors” in the Registrants’ 2021 Form 10-K and Item 1A of Part II of this combined Form 10-Q.

Rate Change Applications

The Registrants are routinely involved in rate change applications before state regulatory authorities. Those applications include general rate cases, where the entire cost of service of the utility is assessed and reset. In addition, Houston Electric is periodically involved in proceedings to adjust its capital tracking mechanisms (TCOS and DCRF) and annually files to adjust its EECRF. CERC is periodically involved in proceedings to adjust its capital tracking mechanisms in Texas (GRIP), its cost of service adjustments in Louisiana and Mississippi (RSP and RRA, respectively), its decoupling mechanism in Minnesota, and its energy efficiency cost trackers in Minnesota and Mississippi (CIP and EECR, respectively). CenterPoint Energy is periodically involved in proceedings to adjust its capital tracking mechanisms in Indiana (CSIA for gas and TDSIC for electric) and Ohio (DRR), its decoupling mechanism in Indiana (SRC for gas), and its energy efficiency cost trackers in Indiana (EEFC for gas and DSMA for electric) and Ohio (EEFR). The table below reflects significant applications pending or completed since the Registrants’ combined 2021 Form 10-K was filed with the SEC through October 28, 2022.

Mechanism

Annual Increase (Decrease) (1)

(in millions)

Filing
Date

Effective Date

Approval Date

Additional Information

CenterPoint Energy and Houston Electric (PUCT)

TCOS

September 2022

October 2022

Based on net change in invested capital of $317 million.

EECRF (1)

June
2022

TBD

The requested amount is comprised of the following: 2023 Program and Evaluation, Measurement and Verification costs of $38 million, a charge of $3 million related to the under-recovery of 2021 program costs including interest and rate case expenses, 2021 earned bonus of $23 million for a total of $64 million. On August 26, 2022, a unanimous settlement was filed for an adjusted total of $63 million comprised of the following: 2023 Program and Evaluation, Measurement and Verification costs of $37 million, a charge of $3 million related to the under-recovery of 2021 program costs including interest and rate case expenses, and a 2021 earned bonus of $23 million.

DCRF (1)

142

April
2022

TBD

As amended on July 1, 2022, the net change in distribution invested capital since its last base rate proceeding of over $1 billion for the period January 1, 2019 through December 31, 2021 for a revenue increase of $86 million, adjusted for load growth. In addition, the request includes approximately $200 million in TEEEF during the calendar year ending December 31, 2021 representing a revenue increase of $57 million. The requested overall revenue increase is $142 million with a proposed effective date of September 1, 2022. On July 11, 2022, a partial settlement was filed resolving the non-mobile generation issues. The settlement provides for a black box reduction to the revenue requirement of $7.8 million for a revenue increase of $78 million and a September 1, 2022 effective date for rates. A hearing on TEEEF issues was held on October 18 through 20, 2022.

TCOS

February 2022

April
2022

April 2022

Based on net change of invested capital of $574 million.

CenterPoint Energy and CERC - Beaumont/East Texas, South Texas, Houston and Texas Coast (Railroad Commission)

GRIP

March 2022

June
2022

Based on net change in invested capital for calendar year 2021 of $213 million.

CenterPoint Energy and CERC - Louisiana (LPSC)

RSP (1)

September 2022

TBD

Based on ROE of 9.95% with 50 basis point (+/-) earnings band. The North Louisiana increase, net of TCJA effects considered outside of the earnings band, is $3 million based on a test year ended June 2022 and adjusted ROE of 7.05%. The South Louisiana increase, net of TCJA effects considered outside of the earnings band, is $5 million based on a test year ended June 2022 and adjusted ROE of 4.19%. The TCJA refund impact to North Louisiana and South Louisiana was $1 million and $1 million, respectively. North Louisiana and South Louisiana also seek to recover regulatory assets due to COVID bad debt expenses in the amounts of $0.7 million and $0.3 million, respectively.

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Mechanism

Annual Increase (Decrease) (1)

(in millions)

Filing
Date

Effective Date

Approval Date

Additional Information

CenterPoint Energy and CERC - Minnesota (MPUC)

CIP Financial Incentive

May 2022

October 2022

September 2022

CIP Financial Incentive based on 2021 CIP program activity.

Rate Case (1)

November 2021

TBD

See discussion above under Minnesota Base Rate Case.

Decoupling

N/A

September 2021

April 2022

Represents under-recovery of approximately $19 million recorded for and during the period July 1, 2020 through June 30, 2021, including an approximately $5 million adjustment related to the implementation of final rates from the general rate case filed in 2019.

CenterPoint Energy and CERC - Mississippi (MPSC)

RRA

April
2022

August 2022

Based on ROE of 9.568% with 100 basis point (+/-) earnings band. Revenue increase of approximately $3 million based on 2021 test year adjusted earned ROE of 7.74%. Interim increase of approximately $1 million implemented May 31, 2022. A joint stipulation was filed on July 29, 2022 resolving all issues and an agreed revenue increase of $2 million based on 2021 test year adjusted earned ROE of 8.27% with rates effective in August 2022.

CenterPoint Energy and CERC - Indiana South - Gas (IURC)

CSIA (1)

October 2022

TBD

Requested an increase of $12 million to rate base, which reflects approximately $1 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until the next rate case. The mechanism also includes a change in (over)/under-recovery variance of ($1 million) annually. Also included are unrecovered deferred O&M expenses of $9 million.

CenterPoint Energy and CERC - Indiana North - Gas (IURC)

CSIA (1)

October 2022

TBD

Requested an increase of $38 million to rate base, which reflects a $3 million
annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until the next rate case. The mechanism also includes a change in (over)/under-recovery variance of ($5 million) annually. Also included is unrecovered deferred O&M expenses of $20 million.

CenterPoint Energy and CERC - Ohio (PUCO)

DRR

April
2022

September 2022

August 2022

Requested an increase of $63 million to rate base for investments made in 2021, which reflects a $9 million annual increase in current revenues. A change in (over)/under-recovery variance of $(4 million) annually is also included in rates. Filed request on September 14, 2022 to extend the DRR beyond 2023 for investment through December 31, 2026.

CenterPoint Energy - Indiana Electric (IURC)

TDSIC (1)

August 2022

TBD

Requested an increase of $43 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of the revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes a change in (over)/under-recovery variance of less than ($1 million).

ECA

May 2022

August 2022

Requested an increase of $21 million to rate base, which reflects a $9 million annual increase in current revenues. 80% of the revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes a change in (over)/under-recovery variance of ($3 million).

TDSIC

February 2022

May
2022

Requested an increase of $42 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of the revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes a change in (over)/under-recovery variance of less than $1 million.

CECA

(2)

February 2022

June
2022

May
2022

Requested a decrease of less than $1 million to rate base, which reflects a $3 million annual decrease in current revenues. The mechanism also includes a change in (over)/under-recovery variance of less than $1 million. This mechanism includes a non-traditional rate making approach related to a 50 MW universal solar array placed in service in January 2021.

(1)Represents proposed increases (decreases) when effective date and/or approval date is not yet determined. Approved rates could differ materially from proposed rates.

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Inflation Reduction Act (IRA)

On August 16, 2022, the IRA was signed into law. The new law extends or creates tax-related energy incentives for solar, wind and alternative clean energy sources, implements a 1% tax on share repurchases after December 31, 2022, and implements a 15% corporate alternative minimum tax based on the AFSI of those corporations with an average AFSI of $1 billion over the most recent three-year period. Although further guidance on the tax provisions of the IRA is expected, the Registrants do not expect the IRA to have a material impact on their 2022 financial results, and they continue to evaluate the IRA provisions for the effect on their future financial results.

Greenhouse Gas Regulation and Compliance (CenterPoint Energy)

On August 3, 2015, the EPA released its CPP rule, which required a 32% reduction in carbon emissions from 2005 levels. The final rule was published in the Federal Register on October 23, 2015, and that action was immediately followed by litigation ultimately resulting in the U.S. Supreme Court staying implementation of the rule. On July 8, 2019, the EPA published the ACE rule, which (i) repealed the CPP rule; (ii) replaced the CPP rule with a program that requires states to implement a program of energy efficiency improvement targets for individual coal-fired electric generating units; and (iii) amended the implementing regulations for Section 111(d) of the Clean Air Act. On January 19, 2021, the majority of the ACE rule — including the CPP repeal, CPP replacement, and the timing-related portions of the Section 111(d) implementing rule — was struck down by the U.S. Court of Appeals for the D.C. Circuit and on October 29, 2021, the U.S. Supreme Court agreed to consider four petitions filed by various coal interests and a coalition of 19 states. On June 30, 2022, the U.S. Supreme Court ruled that the U.S. EPA exceeded its authority in promulgating the CPP. The EPA has announced it plans on issuing new greenhouse gas rules in the future.

The Biden administration recommitted the United States to the Paris Agreement, which can be expected to drive a renewed regulatory push to require further GHG emission reductions from the energy sector and proceeded to lead negotiations at the global climate conference in Glasgow, Scotland. On April 22, 2021, President Biden announced new goals of 50% reduction of economy-wide GHG emissions, and 100% carbon-free electricity by 2035, which formed the basis of the U.S. commitments announced in Glasgow. In September 2021, CenterPoint Energy announced its new net zero emissions goals for both Scope 1 and Scope 2 emissions by 2035 as well as a goal to reduce Scope 3 emissions by 20% to 30% by 2035. Because Texas is an unregulated market, CenterPoint Energy’s Scope 2 estimates do not take into account Texas electric transmission and distribution assets in the line loss calculation and exclude emissions related to purchased power in Indiana between 2024 and 2026 as estimated. CenterPoint Energy’s Scope 3 estimates do not take into account the emissions of transport customers and emissions related to upstream extraction. These emission goals are expected to be used to position CenterPoint Energy to comply with anticipated future regulatory requirements from the current and future administrations to further reduce GHG emissions. CenterPoint Energy’s and CERC’s revenues, operating costs and capital requirements could be adversely affected as a result of any regulatory action that would require installation of new control technologies or a modification of their operations or would have the effect of reducing the consumption of natural gas. The IRA established the Methane Emissions Reduction Program, which imposes a charge on methane emissions from certain natural gas transmission facilities, and the EPA has indicated that it intends to implement new regulations targeting reductions in methane emissions, which are likely to increase costs related to production, transmission and storage of natural gas. Houston Electric, in contrast to some electric utilities including Indiana Electric, does not generate electricity, other than leasing facilities that provide temporary emergency electric energy to aid in restoring power to distribution customers during certain widespread power outages as allowed by a new law enacted after the February 2021 Winter Storm Event, and thus is not directly exposed to the risk of high capital costs and regulatory uncertainties that face electric utilities that burn fossil fuels to generate electricity. CenterPoint Energy’s new net zero emissions goals are aligned with Indiana Electric’s generation transition plan and are expected to position Indiana Electric to comply with anticipated future regulatory requirements related to GHG emissions reductions. Nevertheless, Houston Electric’s and Indiana Electric’s revenues could be adversely affected to the extent any resulting regulatory action has the effect of reducing consumption of electricity by ultimate consumers within their respective service territories. Likewise, incentives to conserve energy or to use energy sources other than natural gas could result in a decrease in demand for the Registrants’ services. For example, Minnesota has enacted the Natural Gas Innovation Act that seeks to provide customers with access to renewable energy resources and innovative technologies, with the goal of reducing GHG emissions. Further, certain local government bodies have introduced or are considering requirements and/or incentives to reduce energy consumption by certain specified dates. For example, Minneapolis has adopted carbon emission reduction goals in an effort to decrease reliance on fossil gas. Additionally, cities in Minnesota within CenterPoint Energy’s Natural Gas operational footprint are considering initiatives to eliminate natural gas use in buildings and focus on electrification. Also, Minnesota cities may consider seeking legislative authority for the ability to enact voluntary enhanced energy standards for all development projects. These initiatives could have a significant impact on CenterPoint Energy and its operations, and this impact could increase if other cities and jurisdictions in its service area enact similar initiatives. Further, our third party suppliers, vendors and partners may also be impacted by climate change laws and regulations, which could impact CenterPoint Energy’s business by, among other things, causing permitting and construction delays, project cancellations or increased project costs passed on to CenterPoint Energy.

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Conversely, regulatory actions that effectively promote the consumption of natural gas because of its lower emissions characteristics would be expected to benefit CenterPoint Energy and CERC and their natural gas-related businesses. At this time, however, we cannot quantify the magnitude of the impacts from possible new regulatory actions related to GHG emissions, either positive or negative, on the Registrants’ businesses.

Compliance costs and other effects associated with climate change, reductions in GHG emissions and obtaining renewable energy sources remain uncertain. Although the amount of compliance costs remains uncertain, any new regulation or legislation relating to climate change will likely result in an increase in compliance costs. While the requirements of a federal or state rule remain uncertain, CenterPoint Energy will continue to monitor regulatory activity regarding GHG emission standards that may affect its business. Currently, CenterPoint Energy does not purchase carbon credits. In connection with its net zero emissions goals, CenterPoint Energy is expected to purchase carbon credits in the future; however, CenterPoint Energy does not currently expect the number of credits, or cost for those credits, to be material.

Climate Change Trends and Uncertainties

As a result of increased awareness regarding climate change, coupled with adverse economic conditions, availability of alternative energy sources, including private solar, microturbines, fuel cells, energy-efficient buildings and energy storage devices, and new regulations restricting emissions, including potential regulations of methane emissions, some consumers and companies may use less energy, meet their own energy needs through alternative energy sources or avoid expansions of their facilities, including natural gas facilities, resulting in less demand for the Registrants’ services. As these technologies become a more cost-competitive option over time, whether through cost effectiveness or government incentives and subsidies, certain customers may choose to meet their own energy needs and subsequently decrease usage of the Registrants’ systems and services, which may result in, among other things, Indiana Electric’s generating facilities becoming less competitive and economical. Further, evolving investor sentiment related to the use of fossil fuels and initiatives to restrict continued production of fossil fuels have had significant impacts on CenterPoint Energy’s electric generation and natural gas businesses. For example, because Indiana Electric’s current generating facilities substantially rely on coal for their operations, certain financial institutions choose not to participate in CenterPoint Energy’s financing arrangements. Conversely, demand for the Registrants’ services may increase as a result of customer changes in response to climate change. For example, as the utilization of electric vehicles increases, demand for electricity may increase, resulting in increased usage of CenterPoint Energy’s systems and services. Any negative opinions with respect to CenterPoint Energy’s environmental practices or its ability to meet the challenges posed by climate change formed by regulators, customers, investors or legislators could harm its reputation.

To address these developments, CenterPoint Energy announced its new net zero emissions goals for both Scope 1 and Scope 2 emissions by 2035. In June of 2020, Indiana Electric identified a preferred generation resource in its most recent IRP submitted to the IURC that aligns with its new net zero emissions goals and includes the replacement of 730 MWs of coal-fired generation facilities with a significant portion comprised of renewables, including solar and wind, supported by dispatchable natural gas combustion turbines, including a pipeline to serve such natural gas generation, as well as storage. Additionally, as reflected in its 10-year capital plan announced in September 2021, CenterPoint Energy anticipates spending over $3 billion in cleaner energy investments and enablement, which may be used to support, among other things, renewable generation and electric vehicle expansion. CenterPoint Energy believes its planned investments in renewable energy generation and corresponding planned reduction in its GHG emissions as part of its newly adopted net zero emissions goals support global efforts to reduce the impacts of climate change.

To the extent climate changes result in warmer temperatures in the Registrants’ service territories, financial results from the Registrants’ businesses could be adversely impacted. For example, CenterPoint Energy’s and CERC’s Natural Gas could be adversely affected through lower natural gas sales. On the other hand, warmer temperatures in CenterPoint Energy’s and Houston Electric’s electric service territory may increase revenues from transmission and distribution and generation through increased demand for electricity used for cooling. Another possible result of climate change is more frequent and more severe weather events, such as hurricanes, tornadoes and flooding, including such storms as the February 2021 Winter Storm Event. Since many of the Registrants’ facilities are located along or near the Texas Gulf Coast, increased or more severe hurricanes or tornadoes could increase costs to repair damaged facilities and restore service to customers. CenterPoint Energy’s previously announced 10-year capital plan includes capital expenditures to maintain reliability and safety and increase resiliency of its systems as climate change may result in more frequent significant weather events. Houston Electric does not own or operate any electric generation facilities other than, since September 2021, leasing facilities that provide temporary emergency electric energy to aid in restoring power to distribution customers during certain widespread power outages as allowed by a new law enacted after the February 2021 Winter Storm Event. Houston Electric transmits and distributes to customers of REPs electric power that the REPs obtain from power generation facilities owned by third parties. To the extent adverse weather conditions affect the Registrants’ suppliers, results from their energy delivery businesses may suffer. For example, in Texas, the February 2021 Winter Storm Event caused an electricity generation shortage that was severely disruptive to Houston Electric’s service territory and the wholesale generation market and also caused a reduction in available natural gas capacity. When the

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Registrants cannot deliver electricity or natural gas to customers, or customers cannot receive services, the Registrants’ financial results can be impacted by lost revenues, and they generally must seek approval from regulators to recover restoration costs. To the extent the Registrants are unable to recover those costs, or if higher rates resulting from recovery of such costs result in reduced demand for services, the Registrants’ future financial results may be adversely impacted. Further, as the intensity and frequency of significant weather events continues, it may impact our ability to secure cost-efficient insurance.

Other Matters

Credit Facilities

The Registrants may draw on their respective revolving credit facilities from time to time to provide funds used for general corporate and limited liability company purposes, including to backstop CenterPoint Energy’s and CERC’s commercial paper programs. The facilities may also be utilized to obtain letters of credit. For further details related to the Registrants’ revolving credit facilities, see Note 11 to the Interim Condensed Financial Statements.

Based on the consolidated debt to capitalization covenant in the Registrants’ revolving credit facilities, the Registrants would have been permitted to utilize the full capacity of such revolving credit facilities, which aggregated approximately $3.6 billion as of September 30, 2022. As of October 24, 2022, the Registrants had the following revolving credit facilities and utilization of such facilities:


			Amount Utilized as of October 24, 2022
Registrant	Size of Facility		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate	Termination Date
	(in millions)
CenterPoint Energy	$	2,400	$	—	$	11	$	691	3.44%	February 4, 2024



Houston Electric	300		—		—		—		—%	February 4, 2024
CERC	900		—		—		559		3.45%	February 4, 2024
Total	$	3,600	$	—	$	11	$	1,250

Borrowings under each of the revolving credit facilities are subject to customary terms and conditions. However, there is no requirement that the borrower makes representations prior to borrowing as to the absence of material adverse changes or litigation that could be expected to have a material adverse effect. Borrowings under each of the revolving credit facilities are subject to acceleration upon the occurrence of events of default that we consider customary. The revolving credit facilities also provide for customary fees, including commitment fees, administrative agent fees, fees in respect of letters of credit and other fees. In each of the revolving credit facilities, the spread to LIBOR and the commitment fees fluctuate based on the borrower’s credit rating. Each of the Registrant’s credit facilities provide for a mechanism to replace LIBOR with possible alternative benchmarks upon certain benchmark replacement events. The borrowers are currently in compliance with the various business and financial covenants in the three revolving credit facilities.

Long-term Debt

For detailed information about the Registrants’ debt transactions in 2022, see Note 11 to the Interim Condensed Financial Statements.

Securities Registered with the SEC

On May 29, 2020, the Registrants filed a joint shelf registration statement with the SEC registering indeterminate principal amounts of Houston Electric’s general mortgage bonds, CERC Corp.’s senior debt securities and CenterPoint Energy’s senior debt securities and junior subordinated debt securities and an indeterminate number of shares of Common Stock, shares of preferred stock, depositary shares, as well as stock purchase contracts and equity units. The joint shelf registration statement will expire on May 29, 2023. For information related to the Registrants’ debt issuances in 2022, see Note 11 to the Interim Condensed Financial Statements.

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Temporary Investments

As of October 24, 2022, the Registrants had no temporary investments.

Money Pool

The Registrants participate in a money pool through which they and certain of their subsidiaries can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the CenterPoint Energy money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper. The net funding requirements of the CERC money pool are expected to be met with borrowings under CERC’s revolving credit facility or the sale of CERC’s commercial paper. The money pool may not provide sufficient funds to meet the Registrants’ cash needs.

The table below summarizes CenterPoint Energy money pool activity by Registrant as of October 24, 2022:


	Weighted Average Interest Rate	Houston Electric		CERC
		(in millions)
Money pool investments (borrowings)	3.48%	$	131	$	—

Impact on Liquidity of a Downgrade in Credit Ratings

The interest rate on borrowings under the credit facilities is based on each respective borrower’s credit ratings. As of October 24, 2022, Moody’s, S&P and Fitch had assigned the following credit ratings to the borrowers:

Moody’s

S&P

Fitch

Registrant

Borrower/Instrument

Rating

Outlook (1)

Rating

Outlook (2)

Rating

Outlook (3)

CenterPoint Energy

CenterPoint Energy Senior Unsecured Debt

Baa2

Stable

BBB

Stable

BBB

Stable

CenterPoint Energy

Vectren Corp. Issuer Rating

n/a

BBB+

Stable

n/a

CenterPoint Energy

Indiana Gas Senior Unsecured Debt

n/a

BBB+

Stable

n/a

CenterPoint Energy

SIGECO Senior Secured Debt

Stable

n/a

Houston Electric

Houston Electric Senior Secured Debt

Stable

CERC

CERC Corp. Senior Unsecured Debt

Stable

BBB+

Stable

A-

Stable

(1)A Moody’s rating outlook is an opinion regarding the likely direction of an issuer’s rating over the medium term.

(2)An S&P outlook assesses the potential direction of a long-term credit rating over the intermediate to longer term.

(3)A Fitch rating outlook indicates the direction a rating is likely to move over a one- to two-year period.

The Registrants cannot assure that the ratings set forth above 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. The Registrants note that these credit ratings are included for informational purposes and are not recommendations to buy, sell or hold the Registrants’ securities and may be revised or withdrawn at any time by the rating agency. Each rating should be evaluated independently of any other rating. Any future reduction or withdrawal of one or more of the Registrants’ credit ratings could have a material adverse impact on the Registrants’ ability to obtain short- and long-term financing, the cost of such financings and the execution of the Registrants’ commercial strategies.

A decline in credit ratings could increase borrowing costs under the Registrants’ revolving credit facilities. If the Registrants’ credit ratings had been downgraded one notch by S&P and Moody’s from the ratings that existed as of September 30, 2022, the impact on the borrowing costs under the three revolving credit facilities would have been insignificant. A decline in credit ratings would also increase the interest rate on long-term debt to be issued in the capital markets and could negatively impact the Registrants’ ability to complete capital market transactions and to access the commercial paper market. Additionally, a decline in credit ratings could increase cash collateral requirements and reduce earnings of CenterPoint Energy’s and CERC’s Natural Gas reportable segments.

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Pipeline tariffs and contracts typically provide that if the credit ratings of a shipper or the shipper’s guarantor drop below a threshold level, which is generally investment grade ratings from both Moody’s and S&P, cash or other collateral may be demanded from the shipper in an amount equal to the sum of three months’ charges for pipeline services plus the unrecouped cost of any lateral built for such shipper. If the credit ratings of CERC Corp. decline below the applicable threshold levels, CERC might need to provide cash or other collateral of as much as $221 million as of September 30, 2022. The amount of collateral will depend on seasonal variations in transportation levels.

ZENS and Securities Related to ZENS (CenterPoint Energy)

If CenterPoint Energy’s creditworthiness were to drop such that ZENS holders thought its liquidity was adversely affected or the market for the ZENS were to become illiquid, some ZENS holders might decide to exchange their ZENS for cash. Funds for the payment of cash upon exchange could be obtained from the sale of the shares of ZENS-Related Securities that CenterPoint Energy owns or from other sources. CenterPoint Energy owns shares of ZENS-Related Securities equal to approximately 100% of the reference shares used to calculate its obligation to the holders of the ZENS. ZENS exchanges result in a cash outflow because tax deferrals related to the ZENS and shares of ZENS-Related Securities would typically cease when ZENS are exchanged or otherwise retired and shares of ZENS-Related Securities are sold. The ultimate tax liability related to the ZENS and ZENS-Related Securities continues to increase by the amount of the tax benefit realized each year, and there could be a significant cash outflow when the taxes are paid as a result of the retirement or exchange of the ZENS. If all ZENS had been exchanged for cash on September 30, 2022, deferred taxes of approximately $659 million would have been payable in 2022. If all the ZENS-Related Securities had been sold on September 30, 2022, capital gains taxes of approximately $68 million would have been payable in 2022 based on 2022 tax rates in effect. For additional information about ZENS, see Note 10 to the Interim Condensed Financial Statements.

Cross Defaults

Under each of CenterPoint Energy’s, Houston Electric’s and CERC’s respective revolving credit facilities, a payment default on, or a non-payment default that permits acceleration of, any indebtedness for borrowed money and certain other specified types of obligations (including guarantees) exceeding $125 million by the borrower or any of their respective significant subsidiaries will cause a default under such borrower’s respective credit facility or term loan agreement. A default by CenterPoint Energy would not trigger a default under its subsidiaries’ debt instruments or revolving credit facilities.

Possible Acquisitions, Divestitures and Joint Ventures

From time to time, the Registrants consider the acquisition or the disposition of assets or businesses or possible joint ventures, strategic initiatives or other joint ownership arrangements with respect to assets or businesses. Any determination to take action in this regard will be based on market conditions and opportunities existing at the time, and accordingly, the timing, size or success of any efforts and the associated potential capital commitments are unpredictable. The Registrants may seek to fund all or part of any such efforts with proceeds from debt and/or equity issuances. Debt or equity financing may not, however, be available to the Registrants at that time due to a variety of events, including, among others, maintenance of our credit ratings, industry conditions, general economic conditions, market conditions and market perceptions. As announced in September 2021 and updated in November 2022, CenterPoint Energy has increased its planned capital expenditures in its Electric and Natural Gas businesses to support rate base growth and may explore asset sales, in addition to the recently completed sale of its Natural Gas businesses located in Arkansas and Oklahoma, as a means to efficiently finance a portion of such increased capital expenditures. For further information, see Note 3 to the Interim Condensed Financial Statements.

Hedging of Interest Expense for Future Debt Issuances

From time to time, the Registrants may enter into interest rate agreements to hedge, in part, volatility in the U.S. treasury rates by reducing variability in cash flows related to interest payments. For further information, see Note 7(a) to the Interim Condensed Financial Statements.

Collection of Receivables from REPs (CenterPoint Energy and Houston Electric)

Houston Electric’s receivables from the distribution of electricity are collected from REPs that supply the electricity Houston Electric distributes to their customers. Before conducting business, a REP must register with the PUCT and must meet certain financial qualifications. Nevertheless, adverse economic conditions, the February 2021 Winter Storm Event, structural problems in the market served by ERCOT or financial difficulties of one or more REPs could impair the ability of these REPs to pay for Houston Electric’s services or could cause them to delay such payments. Houston Electric depends on these REPs to remit payments on a timely basis, and any delay or default in payment by REPs could adversely affect Houston Electric’s cash flows. In the event of a REP default, Houston Electric’s tariff provides a number of remedies, including the option for Houston

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Electric to request that the PUCT suspend or revoke the certification of the REP. Applicable regulatory provisions require that customers be shifted to another REP or a provider of last resort if a REP cannot make timely payments. However, Houston Electric remains at risk for payments related to services provided prior to the shift to the replacement REP or the provider of last resort. If a REP were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event such REP might seek to avoid honoring its obligations and claims might be made against Houston Electric involving payments it had received from such REP. If a REP were to file for bankruptcy, Houston Electric may not be successful in recovering accrued receivables owed by such REP that are unpaid as of the date the REP filed for bankruptcy. However, PUCT regulations authorize utilities, such as Houston Electric, to defer bad debts resulting from defaults by REPs for recovery in future rate cases, subject to a review of reasonableness and necessity.

Other Factors that Could Affect Cash Requirements

In addition to the above factors, the Registrants’ liquidity and capital resources could also be negatively affected by:

•cash collateral requirements that could exist in connection with certain contracts and natural gas purchases, natural gas price and natural gas storage activities of CenterPoint Energy’s and CERC’s Natural Gas reportable segment;

•acceleration of payment dates on certain gas supply contracts, under certain circumstances, as a result of increased natural gas prices and concentration of natural gas suppliers (CenterPoint Energy and CERC);

•increased costs related to the acquisition of natural gas (CenterPoint Energy and CERC);

•increases in interest expense in connection with debt refinancings and borrowings under credit facilities or term loans due to rising interest rates or the use of alternative sources of financings;

•increases in commodity prices and inflation rates;

•various legislative or regulatory actions, including recovery of costs such as those associated with the TEEEF leases;

•incremental collateral, if any, that may be required due to regulation of derivatives (CenterPoint Energy);

•the ability of REPs, including REP affiliates of NRG and Vistra Energy Corp., to satisfy their obligations to CenterPoint Energy and Houston Electric, including the negative impact on such ability related to the February 2021 Winter Storm Event;

•slower customer payments and increased write-offs of receivables due to higher natural gas prices, changing economic conditions or the February 2021 Winter Storm Event (CenterPoint Energy and CERC);

•the satisfaction of any obligations pursuant to guarantees;

•contributions to pension and postretirement benefit plans;

•restoration costs and revenue losses resulting from future natural disasters such as hurricanes and the timing of recovery of such restoration costs; and

•various other risks identified in “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2021 Form 10-K and in Item 1A of Part II of this combined Form 10-Q.

Certain Contractual Limits on Our Ability to Issue Securities and Borrow Money

For information about the total debt to capitalization financial covenants in the Registrants’ and certain of CenterPoint Energy’s subsidiaries’ revolving credit facilities, see Note 11 to the Interim Condensed Financial Statements.

CRITICAL ACCOUNTING POLICIES

A critical accounting policy is one that is both important to the presentation of the Registrants’ financial condition and results of operations and requires management to make difficult, subjective or complex accounting estimates. An accounting estimate is an approximation made by management of a financial statement element, item or account in the financial statements. Accounting estimates in the Registrants’ historical consolidated financial statements measure the effects of past business transactions or events, or the present status of an asset or liability. Additionally, different estimates that the Registrants could have used or changes in an accounting estimate that are reasonably likely to occur could have a material impact on the presentation of their financial condition, results of operations or cash flows. The circumstances that make these judgments difficult, subjective and/or complex have to do with the need to make estimates about the effect of matters that are inherently uncertain. Estimates and assumptions about future events and their effects cannot be predicted with certainty. The Registrants base their estimates on historical experience and on various other assumptions that they believe to be reasonable under the circumstances, the results of which form the basis for making judgments. These estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the Registrants’ operating environment changes.

Impairment of Long-Lived Assets, Including Identifiable Intangibles and Goodwill

The Registrants review the carrying value of long-lived assets, including identifiable intangibles, goodwill, and investments without a readily determinable fair value, whenever events or changes in circumstances indicate that such carrying values may

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not be recoverable, and at least annually, goodwill is tested for impairment as required by accounting guidance for goodwill and other intangible assets. Unforeseen events, changes in market conditions, and probable regulatory disallowances, where applicable, could have a material effect on the value of long-lived assets, including intangibles, goodwill, and investments without a readily determinable fair value due to changes in observable or estimated market value, future cash flows, interest rate, and regulatory matters could result in an impairment charge.

Annual goodwill impairment test

CenterPoint Energy and CERC completed their 2022 annual goodwill impairment test during the third quarter of 2022 and determined, based on an income approach or a weighted combination of income and market approaches, that no goodwill impairment charge was required for any reporting unit. The fair values of each reporting unit significantly exceeded the carrying value of the reporting unit.

Although no goodwill impairment resulted from the 2022 annual test, an interim goodwill impairment test could be triggered by the following: actual earnings results that are materially lower than expected, significant adverse changes in the operating environment, an increase in the discount rate, changes in other key assumptions which require judgment and are forward looking in nature, if CenterPoint Energy’s market capitalization falls below book value for an extended period of time, or events affecting a reporting unit such as a contemplated disposal of all or part of a reporting unit.

Common control transactions (CenterPoint Energy and CERC)

When accounting for a transfer of net assets or exchange of equity interests between entities under common control, the entity that receives the net assets or the equity interests shall initially recognize the assets and liabilities transferred at the date of transfer based on the ultimate parent company’s basis, which in the case of the Restructuring is CenterPoint Energy’s basis. CenterPoint Energy’s basis in net assets of an entity may differ from the historical net assets of that entity on a standalone basis, for example, because push-down accounting had not been applied on a standalone basis. Additionally, when the net assets transferred in a common-control transaction meet the definition of a business, the receiving entity will record an allocation of goodwill from the reporting unit based on the relative fair value of the businesses transferred within that reporting unit. As a result, on June 30, 2022, CERC received $972 million of goodwill from CenterPoint Energy’s Natural Gas reporting unit in connection with the Restructuring. CERC recast prior periods to reflect the Restructuring as if it occurred at the earliest period presented for which CenterPoint Energy had common control. The Restructuring did not impact CenterPoint Energy’s basis in any entity, its allocation of goodwill to its reporting units, or its segment presentation. Neither CenterPoint Energy nor CERC recognized any gains or losses in connection with the Restructuring. SIGECO was not acquired by CERC and remains a subsidiary of VUH.

Fair value is the amount at which an asset, liability or business could be bought or sold in a current transaction between willing parties and may be estimated using a number of techniques, including quoted market prices, present value techniques based on estimates of cash flows, or multiples of earnings or revenue performance measures. The fair value could be different if different estimates and assumptions in these valuation techniques were applied.

Fair value measurements require significant judgment and often depend on unobservable inputs, including (i) projected timing and amounts of future cash flows, which factor in planned growth initiatives, (ii) the regulatory environment, as applicable, and (iii) discount rates reflecting risk inherent in the future market prices. Changes in these assumptions could have a significant impact on the resulting fair value or relative fair value.

The fair value of the businesses within the Natural Gas reporting unit was estimated based on a weighted combination of income and market approaches, consistent with the methodology used in the 2021 annual goodwill impairment test.

Other than the annual goodwill impairment test and the common control transaction discussed above, there have been no significant changes in our critical accounting policies during the three and nine months ended September 30, 2022, as compared to the critical accounting policies disclosed in Management’s Discussion and Analysis of Financial Condition and Results of Operations included in the Registrants’ combined 2021 Form 10-K.

Item 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Houston Electric and CERC meet the conditions specified in General Instruction H(1)(a) and (b) to Form 10-Q and are therefore permitted to use the reduced disclosure format for wholly-owned subsidiaries of reporting companies. Accordingly, Houston Electric and CERC have omitted from this report the information called for by Item 3 (Quantitative and Qualitative Disclosures About Market Risk) of Part I of the Form 10-Q.

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Interest Rate Risk (CenterPoint Energy)

As of September 30, 2022, CenterPoint Energy had outstanding long-term debt, lease obligations and obligations under its ZENS that subject it to the risk of loss associated with movements in market interest rates.

CenterPoint Energy’s floating rate obligations aggregated $3.0 billion and $4.5 billion as of September 30, 2022 and December 31, 2021, respectively. If the floating interest rates were to increase by 10% from September 30, 2022 rates, CenterPoint Energy’s combined interest expense would increase by approximately $8 million annually.

As of September 30, 2022 and December 31, 2021, CenterPoint Energy had outstanding fixed-rate debt (excluding indexed debt securities) aggregating $12.7 billion and $11.7 billion, respectively, in principal amount and having a fair value of $11.2 billion and $13.0 billion, respectively. Because these instruments are fixed-rate, they do not expose CenterPoint Energy to the risk of loss in earnings due to changes in market interest rates. However, the fair value of these instruments would increase by approximately $542 million if interest rates were to decline by 10% from levels at September 30, 2022. In general, such an increase in fair value would impact earnings and cash flows only if CenterPoint Energy were to reacquire all or a portion of these instruments in the open market prior to their maturity.

In general, such an increase in fair value would impact earnings and cash flows only if CenterPoint Energy were to reacquire all or a portion of these instruments in the open market prior to their maturity.

The ZENS obligation is bifurcated into a debt component and a derivative component. The debt component of $8 million as of September 30, 2022 was a fixed-rate obligation and, therefore, did not expose CenterPoint Energy to the risk of loss in earnings due to changes in market interest rates. However, the fair value of the debt component would increase by approximately $1 million if interest rates were to decline by 10% from levels at September 30, 2022. Changes in the fair value of the derivative component, a $522 million recorded liability at September 30, 2022, are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income and, therefore, it is exposed to changes in the fair value of the derivative component as a result of changes in the underlying risk-free interest rate. If the risk-free interest rate were to increase by 10% from September 30, 2022 levels, the fair value of the derivative component liability would decrease by less than $1 million, which would be recorded as an unrealized gain in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Equity Market Value Risk (CenterPoint Energy)

CenterPoint Energy is exposed to equity market value risk through its ownership of 10.2 million shares of AT&T Common, 0.9 million shares of Charter Common and 2.5 million shares of WBD Common, which CenterPoint Energy holds to facilitate its ability to meet its obligations under the ZENS. See Note 10 to the Interim Condensed Financial Statements for a discussion of CenterPoint Energy’s ZENS obligation. Changes in the fair value of the ZENS-Related Securities held by CenterPoint Energy are expected to substantially offset changes in the fair value of the derivative component of the ZENS. A decrease of 10% from the September 30, 2022 aggregate market value of these shares would result in a net loss of less than $1 million, which would be recorded as a loss in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Commodity Price Risk From Non-Trading Activities (CenterPoint Energy and CERC)

CenterPoint Energy’s and CERC’s regulated operations in Indiana have limited exposure to commodity price risk for transactions involving purchases and sales of natural gas, coal and purchased power for the benefit of retail customers due to current state regulations, which, subject to compliance with those regulations, allow for recovery of the cost of such purchases through natural gas and fuel cost adjustment mechanisms. CenterPoint Energy’s and CERC’s utility natural gas operations in Indiana have regulatory authority to lock in pricing for up to 50% of annual natural gas purchases using arrangements with an original term of up to 10 years. This authority has been utilized to secure fixed price natural gas using both physical purchases and financial derivatives. As of September 30, 2022, the recorded fair value of non-trading energy derivative assets was $34 million and $27 million, respectively, for CenterPoint Energy’s and CERC’s utility natural gas operations in Indiana.

Although CenterPoint Energy’s and CERC’s regulated operations are exposed to limited commodity price risk, natural gas and coal prices have other effects on working capital requirements, interest costs, and some level of price-sensitivity in volumes sold or delivered. Constructive regulatory orders, such as those authorizing lost margin recovery, other innovative rate designs and recovery of unaccounted for natural gas and other natural gas-related expenses, also mitigate the effect natural gas costs may have on CenterPoint Energy’s financial condition. In 2008, the PUCO approved an exit of the merchant function in CenterPoint Energy’s and CERC’s Ohio natural gas service territory, allowing Ohio customers to purchase substantially all natural gas directly from retail marketers rather than from CenterPoint Energy or CERC.

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Item 4.CONTROLS AND PROCEDURES

In accordance with Exchange Act Rules 13a-15 and 15d-15, the Registrants carried out separate evaluations, under the supervision and with the participation of each company’s management, including the principal executive officer and principal financial officer, of the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report. Based on those evaluations, the principal executive officer and principal financial officer, in each case, concluded that the disclosure controls and procedures were effective as of September 30, 2022 to provide assurance that information required to be disclosed in the reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding disclosure.

There has been no change in the Registrants’ internal controls over financial reporting that occurred during the three months ended September 30, 2022 that has materially affected, or is reasonably likely to materially affect, the Registrants’ internal controls over financial reporting.

PART II. OTHER INFORMATION

Item 1.LEGAL PROCEEDINGS

For a description of certain legal and regulatory proceedings, please read Note 13(d) to the Interim Condensed Financial Statements and “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Future Sources and Uses of Cash” and “— Regulatory Matters,” each of which is incorporated herein by reference. See also “Business — Regulation” and “— Environmental Matters” in Item 1 and “Legal Proceedings” in Item 3 of the Registrants’ combined 2021 Form 10-K.

Item 1A.RISK FACTORS

Except for the updates below, there have been no material changes from the risk factors disclosed in the Registrants’ combined 2021 Form 10-K. The following risk factor should be read in conjunction with the risk factors described in the Registrants’ combined 2021 Form 10-K.

Increases in the cost or reduction in supply of solar energy system components due to tariffs or trade restrictions imposed by the U.S. government may have an adverse effect on our business, financial condition and results of operations.

China is a major producer of solar cells and other solar products. Certain solar cells, modules, laminates and panels from China are subject to various antidumping and countervailing duty rates, depending on the exporter supplying the product, imposed by the U.S. government as a result of determinations that the U.S. was materially injured as a result of such imports being sold at less than fair value and subsidized by the Chinese government. In March 2022, the DOC announced that it would initiate an investigation into whether imports of solar cells and panels produced in Cambodia, Malaysia, Thailand and Vietnam are circumventing rules, such as anti-dumping and countervailing duties, intended to impose a tariff on imports of solar cells and panels manufactured in China. If an affirmative finding is made by the DOC, it could impose duties on imports of solar cells and panels from Cambodia, Malaysia, Thailand and Vietnam with both forward-looking and retroactive application. If enacted, these or similar duties could put upward pressure on prices of these solar energy products, which may reduce our ability to acquire these items in a timely and cost-efficient manner. If we are unable to secure such solar energy products in a timely and cost-efficient manner, we may be forced to delay, downsize and/or cancel solar projects and we may not be able to procure the resources needed to fully execute on our ten-year capital plan or achieve our net zero emissions goals. Additionally, delays or cancellations by developers of third-party solar power facilities expected to interconnect with CenterPoint Energy’s and Houston Electric’s system may have adverse impacts, such as delayed or reduced potential future revenues. We cannot predict what additional actions the U.S. government may adopt with respect to tariffs or other trade regulations in the future or what actions may be taken by other countries in retaliation for such measures. If an affirmative finding is made by the DOC or other additional measures are imposed, our business, financial condition and results of operations may be adversely affected.

Item 5.OTHER INFORMATION

None.

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Item 6.EXHIBITS

Exhibits filed herewith are designated by a cross (†); all exhibits not so designated are incorporated by reference to a prior filing as indicated. Agreements included as exhibits are included only to provide information to investors regarding their terms. Agreements listed below may contain representations, warranties and other provisions that were made, among other things, to provide the parties thereto with specified rights and obligations and to allocate risk among them, and no such agreement should be relied upon as constituting or providing any factual disclosures about the Registrants, any other persons, any state of affairs or other matters.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, the Registrants have not filed as exhibits to this combined Form 10-Q certain long-term debt instruments, including indentures, under which the total amount of securities authorized does not exceed 10% of the total assets of the Registrants and its subsidiaries on a consolidated basis. The Registrants hereby agree to furnish a copy of any such instrument to the SEC upon request.

Exhibit
Number

Description

Report or Registration
Statement

SEC File or
Registration
Number

Exhibit
Reference

CenterPoint Energy

Houston Electric

CERC

2.1*

Agreement and Plan of Merger, dated as of April 21, 2018, by and among Vectren Corporation, CenterPoint Energy, Inc. and Pacer Merger Sub, Inc.

CenterPoint Energy’s Form 8-K dated April 21, 2018

1-31447

2.1

2.2*

Securities Purchase Agreement, dated as of February 3, 2020, by and among Vectren Utility Services, Inc., PowerTeam Services, LLC and, solely for purposes of Section 10.17 of the Securities Purchase Agreement, Vectren Corporation

CenterPoint Energy’s Form 8-K dated February 3, 2020

1-31447

2.1

2.3*

Equity Purchase Agreement, dated as of February 24, 2020, by and between CERC Corp. and Athena Energy Services Buyer, LLC

CenterPoint Energy’s Form 8-K dated February 24, 2020

1-31447

2.1

2.4*

Asset Purchase Agreement, by and between CenterPoint Energy Resources Corp. and Southern Col Midco, LLC, dated as of April 29, 2021

CenterPoint Energy’s Form 10-Q for the quarter ended March 31, 2021

1-31447

2.4

3.1

Restated Articles of Incorporation of CenterPoint Energy

CenterPoint Energy’s Form 8-K dated July 24, 2008

1-31447

3.2

Restated Certificate of Formation of Houston Electric

Houston Electric’s Form 10-Q for the quarter ended June 30, 2011

1-3187

3.1

3.3

Certificate of Incorporation of RERC Corp.

CERC Form 10-K for the year ended December 31, 1997

1-13265

3(a)(1)

3.4

Certificate of Merger merging former NorAm Energy Corp. with and into HI Merger, Inc. dated August 6, 1997

CERC Form 10-K for the year ended December 31, 1997

1-13265

3(a)(2)

3.5

Certificate of Amendment changing the name to Reliant Energy Resources Corp.

CERC Form 10-K for the year ended December 31, 1998

1-13265

3(a)(3)

3.6

Certificate of Amendment changing the name to CenterPoint Energy Resources Corp.

CERC Form 10-Q for the quarter ended June 30, 2003

1-13265

3(a)(4)

3.7

Third Amended and Restated Bylaws of CenterPoint Energy

CenterPoint Energy’s Form 8-K dated February 21, 2017

1-31447

3.1

3.8

Amended and Restated Limited Liability Company Agreement of Houston Electric

Houston Electric’s Form 10-Q for the quarter ended June 30, 2011

1-3187

3.2

3.9

Bylaws of RERC Corp.

CERC Form 10-K for the year ended December 31, 1997

1-13265

3(b)

3.10

Statement of Resolutions Deleting Shares Designated Series A Preferred Stock of CenterPoint Energy

CenterPoint Energy’s Form 10-K for the year ended December 31, 2011

1-31447

3(c)

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Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
3.11	Statement of Resolution Establishing Series of Shares Designated Series A Fixed-to-Floating Rate Cumulative Redeemable Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated August 22, 2018	1-31447	3.1	x
3.12	Statement of Resolution Establishing Series of Shares designated 7.00% Series B Mandatory Convertible Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated September 25, 2018	1-31447	3.1	x
3.13	Statement of Resolution Establishing Series of Shares designated Series C Mandatory Convertible Preferred Stock of CenterPoint Energy, Inc., filed with the Secretary of State of the State of Texas and effective May 7, 2020	CenterPoint Energy’s Form 8-K dated May 6, 2020	1-31447	3.1	x
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1	x
4.2	Form of Certificate representing the Series A Fixed-to-Floating Rate Cumulative Redeemable Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated August 22, 2018	1-31447	4.1	x
4.3	General Mortgage Indenture, dated as of October 10, 2002, between CenterPoint Energy Houston Electric, LLC and JPMorgan Chase Bank, as Trustee	Houston Electric’s Form 10-Q for the quarter ended September 30, 2002	1-3187	4(j)(1)		x
4.4	Ninth Supplemental Indenture to Exhibit 4.3 , dated as of November 12, 2002	CenterPoint Energy’s Form 10-K for the year ended December 31, 2002	1-31447	4(e)(10)		x
4.5	Twentieth Supplemental Indenture to Exhibit 4.3 , dated as of December 9, 2008	Houston Electric’s Form 8-K dated January 6, 2009	1-3187	4.2		x
4.6	Thirty-Second Supplemental Indenture to Exhibit 4.3 , dated as of September 15, 2022	Houston Electric’s Form 8-K dated September 12, 2022	1-3187	4.4		x
†4.7	Officer’s Certificate, dated September 15, 2022, setting forth the form, terms and provisions of the Thirty-Fifth and Thirty Sixth Series of General Mortgage Bonds					x
4.8	Indenture, dated as of February 1, 1998, between CenterPoint Energy Resources Corp. (formerly NorAm Energy Corp.) and The Bank of New York Mellon Trust Company, National Association (successor JPMorgan Chase Bank, National Association (formerly Chase Bank of Texas)), as trustee	CERC’s Form 8-K dated February 5, 1998	1-13265	4.1			x
4.9	Supplemental Indenture No. 22 to Exhibit 4.8 dated as of October 5, 2022	CERC’s Form 8-K dated October 5, 2022	1-13265	4.2			x

Table of Contents

Exhibit
Number

Description

Report or Registration
Statement

SEC File or
Registration
Number

Exhibit
Reference

CenterPoint Energy

Houston Electric

CERC

4.10

Registration Rights Agreement, dated as of October 5, 2022, between CenterPoint Energy Resources Corp. and Goldman Sachs & Co. LLC

CERC’s Form 8-K dated October 5, 2022

1-13265

4.3

10.1

$500,000,000 Term Loan Agreement dated as of August 23, 2022 among CenterPoint Energy Resources Corp., as Borrower, Mizuho Bank, Ltd., as Administrative Agent, and the banks named therein

CERC’s Form 8-K dated August 23, 2022

1-13265

10.1

†31.1.1

Rule 13a-14(a)/15d-14(a) Certification of David J. Lesar

†31.1.2

Rule 13a-14(a)/15d-14(a) Certification of Scott E. Doyle

†31.1.3

Rule 13a-14(a)/15d-14(a) Certification of Scott E. Doyle

†31.2.1

Rule 13a-14(a)/15d-14(a) Certification of Jason P. Wells

†31.2.2

Rule 13a-14(a)/15d-14(a) Certification of Jason P. Wells

†31.2.3

Rule 13a-14(a)/15d-14(a) Certification of Jason P. Wells

†32.1.1

Section 1350 Certification of David J. Lesar

†32.1.2

Section 1350 Certification of Scott E. Doyle

†32.1.3

Section 1350 Certification of Scott E. Doyle

†32.2.1

Section 1350 Certification of Jason P. Wells

†32.2.2

Section 1350 Certification of Jason P. Wells

†32.2.3

Section 1350 Certification of Jason P. Wells

†101.INS

Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document

†101.SCH

Inline XBRL Taxonomy Extension Schema Document

†101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

†101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

†101.LAB

Inline XBRL Taxonomy Extension Labels Linkbase Document

†101.PRE

Inline XBRL Taxonomy Extension Presentation Linkbase Document

†104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)


*			Schedules to this agreement have been omitted pursuant to Items 601(a)(5) and 601(b)(2) of Regulation S-K. A copy of any omitted schedules will be furnished supplementally to the SEC upon request; provided, however, that the parties may request confidential treatment pursuant to Rule 24b-2 of the Exchange Act for any document so furnished.

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SIGNATURES

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


			CENTERPOINT ENERGY, INC.
			CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
			CENTERPOINT ENERGY RESOURCES CORP.


By:			/s/ Kara Gostenhofer Ryan
			Kara Gostenhofer Ryan
			Vice President and Chief Accounting Officer

Date: November 1, 2022

Document

Exhibit 4.7

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC

OFFICER’S CERTIFICATE

SEPTEMBER 15, 2022

I, the undersigned officer of CenterPoint Energy Houston Electric, LLC, a Texas limited liability company (the “Company”), do hereby certify that I am an Authorized Officer of the Company as such term is defined in the Indenture (as defined herein). I am delivering this certificate pursuant to the authority granted in the Resolutions adopted by written consent of the sole Manager of the Company dated September 2, 2022, and Sections 105, 201, 301, 401(1), 401(5) and 1403 of the General Mortgage Indenture, dated as of October 10, 2002, as heretofore supplemented to the date hereof (as heretofore supplemented, the “Indenture”), between the Company and The Bank of New York Mellon Trust Company, National Association (successor in trust to JPMorgan Chase Bank), as Trustee (the “Trustee”). Terms used herein and not otherwise defined herein shall have the meanings assigned to them in the Indenture, unless the context clearly requires otherwise. Based upon the foregoing, I hereby certify on behalf of the Company as follows:

1. The terms and conditions of the Securities of the series described in this Officer’s Certificate are as follows (the numbered subdivisions set forth in this Paragraph 1 corresponding to the numbered subdivisions of Section 301 of the Indenture):

(1) The Securities of the thirty-fifth series to be issued under the Indenture shall be designated as the “4.45% General Mortgage Bonds, Series AI, due 2032” (the “Series AI Mortgage Bonds”), as set forth in the Thirty-Second Supplemental Indenture, dated as of the date hereof, between the Company and the Trustee. The Securities of the thirty-sixth series to be issued under the Indenture shall be designated as the “4.85% General Mortgage Bonds, Series AJ, due 2052” (the “Series AJ Mortgage Bonds” and together with the Series AI Mortgage Bonds, the “Bonds”), as set forth in the Thirty-Second Supplemental Indenture, dated as of the date hereof, between the Company and the Trustee.

(2) The Trustee shall authenticate and deliver the Series AI Mortgage Bonds and Series AJ Mortgage Bonds for original issue on September 15, 2022 (the “Issue Date”) in the aggregate principal amount of $500,000,000 and $300,000,000, respectively, upon a Company Order for the authentication and delivery thereof and satisfaction of Section 401 of the Indenture; provided, however, that, as contemplated in the second paragraph of Section 301 of the Indenture and the definition of “Tranche” in Section 101 of the Indenture, additional Securities of a series or Tranche may be subsequently issued from time to time, without any consent of Holders of the Securities of such series, pursuant to Section 1401(4) of the Indenture.

(3) Interest on the Bonds shall be payable to the Persons in whose names such Securities are registered at the close of business on the Regular Record Date for such interest (as specified in (5) below), except as otherwise expressly provided in the form of such Securities attached hereto as Exhibit A.

(4) The Series AI Mortgage Bonds shall mature and the principal thereof shall be due and payable together with all accrued and unpaid interest thereon on October 1, 2032. The Series AJ Mortgage Bonds shall mature and the principal thereof shall be due and payable together with all accrued and unpaid interest thereon on October 1, 2052.

(5) The Series AI Mortgage Bonds shall bear interest at the rate of 4.45% per annum. The Series AJ Mortgage Bonds shall bear interest at the rate of 4.85% per annum.

Interest shall accrue on the Bonds from the Issue Date, or the most recent date to which interest has been paid or duly provided for. The Interest Payment Dates for the Bonds shall be April 1 and October 1 in each year commencing April 1, 2023, and the Regular Record Dates with respect to the Interest Payment Dates for the Bonds shall be the March 15 and September 15, respectively, immediately preceding each Interest Payment Date (whether or not a Business Day); provided however that interest payable at maturity, upon redemption or when principal is otherwise due will be payable to the Holder to whom principal is payable.

(6) The Corporate Trust Office of The Bank of New York Mellon Trust Company, National Association in New York, New York shall be the place at which (i) the principal of and premium, if any, and interest on the Bonds shall be payable, (ii) registration of transfer of the Bonds may be effected, (iii) exchanges of the Bonds may be effected, and (iv) notices and demands to or upon the Company in respect of the Bonds and the Indenture may be served; and The Bank of New York Mellon Trust Company, National Association shall be the Security Registrar and Paying Agent for the Bonds; provided, however, that the Company reserves the right to change, by one or more Officer’s Certificates, any such place or the Security Registrar; and provided, further, that the Company reserves the right to designate, by one or more Officer’s Certificates, its principal office in Houston, Texas as any such place or itself as the Security Registrar; provided, however, that there shall be only a single Security Registrar for each series of Bonds.

(7) Prior to July 1, 2032, in the case of the Series AI Mortgage Bonds (the “Series AI Par Call Date”), or April 1, 2052, in the case of the Series AJ Mortgage Bonds (the “Series AJ Par Call Date”; the Series AI Par Call Date and the Series AJ Par Call Date are each a “Par Call Date”), the Company may redeem the Series AI Mortgage Bonds or the Series AJ Mortgage Bonds, respectively, in whole or in part, at any time and from time to time, at a redemption price (expressed as a percentage of principal amount and rounded to three decimal places) equal to the greater of:

•(1)(a) the sum of the present values of the remaining scheduled payments of principal and interest on the Bonds of such series to be redeemed discounted to the Redemption Date (assuming the Bonds to be redeemed matured on the applicable Par Call Date) on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 20 basis points in the case of the Series AI Mortgage Bonds and 25 basis points in the case of the Series AJ Mortgage Bonds; less (b) interest accrued to the Redemption Date; and

•(2) 100% of the principal amount of the Bonds to be redeemed;

plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date.

On or after the Series AI Par Call Date, in the case of the Series AI Mortgage Bonds, or the Series AJ Par Call Date, in the case of the Series AJ Mortgage Bonds, the Company may redeem the Series AI Mortgage Bonds or the Series AJ Mortgage Bonds, respectively, in whole or in part, at any time and from time to time, at a redemption price equal to 100% of the principal amount of Bonds being redeemed plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the yield determined by the Company in accordance with the following two paragraphs.

day that appear after such time on such day in the most recent statistical release published by the Board of Governors of the Federal Reserve System designated as “Selected Interest Rates (Daily) - H.15” (or any successor designation or publication) (“H.15”) under the caption “U.S. government securities–Treasury constant maturities–Nominal” (or any successor caption or heading) (“H.15 TCM”). In determining the Treasury Rate, the Company shall select, as applicable: (1) the yield for the Treasury constant maturity on H.15 exactly equal to the period from the Redemption Date to the applicable Par Call Date (the “Remaining Life”); or (2) if there is no such Treasury constant maturity on H.15 exactly equal to the Remaining Life, the two yields – one yield corresponding to the Treasury constant maturity on H.15 immediately shorter than and one yield corresponding to the Treasury constant maturity on H.15 immediately longer than the Remaining Life – and shall interpolate to the applicable Par Call Date on a straight-line basis (using the actual number of days) using such yields and rounding the result to three decimal places; or (3) if there is no such Treasury constant maturity on H.15 shorter than or longer than the Remaining Life, the yield for the single Treasury constant maturity on H.15 closest to the Remaining Life. For purposes of this paragraph, the applicable Treasury constant maturity or maturities on H.15 shall be deemed to have a maturity date equal to the relevant number of months or years, as applicable, of such Treasury constant maturity from the Redemption Date.

If on the third Business Day preceding the Redemption Date H.15 TCM or any successor designation or publication is no longer published, the Company shall calculate the Treasury Rate based on the rate per annum equal to the semi-annual equivalent yield to maturity at 11:00 a.m., New York City time, on the second Business Day preceding such Redemption Date of the United States Treasury security maturing on, or with a maturity that is closest to, the applicable Par Call Date, as applicable. If there is no United States Treasury security maturing on the applicable Par Call Date but there are two or more United States Treasury securities with a maturity date equally distant from the applicable Par Call Date, one with a maturity date preceding the applicable Par Call Date and one with a maturity date following the applicable Par Call Date, the Company shall select the United States Treasury security with a maturity date preceding the applicable Par Call Date. If there are two or more United States Treasury securities maturing on the applicable Par Call Date or two or more United States Treasury securities meeting the criteria of the preceding sentence, the Company shall select from among these two or more United States Treasury securities the United States Treasury security that is trading closest to par based upon the average of the bid and asked prices for such United States Treasury securities at 11:00 a.m., New York City time. In determining the Treasury Rate in accordance with the terms of this paragraph, the semi-annual yield to maturity of the applicable United States Treasury security shall be based upon the average of the bid and asked prices (expressed as a percentage of principal amount) at 11:00 a.m., New York City time, of such United States Treasury security, and rounded to three decimal places.

The Company’s actions and determinations in determining the redemption price shall be conclusive and binding for all purposes, absent manifest error.

The Trustee, at the written direction of the Company, will send a notice of redemption to each holder of Bonds to be redeemed by first-class mail (or in accordance with the procedures of The Depository Trust Company with respect to Bonds registered in the name of Cede & Co.) at least 10 and not more than 60 days prior to the date fixed for redemption. Unless the Company defaults on payment of the redemption price, interest will cease to accrue on the Bonds or portions thereof called for redemption on the Redemption Date. If fewer than all of the Bonds of a series are to be redeemed, not more than 60 days prior to the Redemption Date, the particular Bonds of that series or portions thereof called for redemption will be selected from the outstanding Bonds of that series

not previously called by such method as the Trustee deems fair and appropriate. The Trustee may select for redemption Bonds and portions of Bonds in amounts of $2,000 or whole multiples of $1,000. In the case of a partial redemption of Bonds registered in the name of Cede & Co., the Bonds to be redeemed will be determined in accordance with the procedures of The Depository Trust Company.

(8) Not applicable.

(9) The Bonds will be issued in minimum denominations of $2,000 and integral multiples of $1,000 in excess thereof.

(10) Not applicable.

(11) Not applicable.

(12) Not applicable.

(13) See subsection (7) above.

(14) Not applicable.

(15) Not applicable.

(16) Not applicable.

(17) The Bonds shall be issuable in whole or in part in the form of one or more Global Securities (as defined below). The Depository Trust Company shall initially serve as Depositary (as defined below) with respect to the Global Securities. “Depositary” means, with respect to Securities of any series issuable in whole or in part in the form of one or more Global Securities, a clearing agency registered under the Exchange Act that is designated to act as depositary for such Securities. “Global Security” means a Security that evidences all or part of the Securities of a series and bears a legend in substantially the following form:

THIS SECURITY IS IN GLOBAL FORM AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE OF A DEPOSITARY. THIS SECURITY IS EXCHANGEABLE FOR SECURITIES REGISTERED IN THE NAME OF A PERSON OTHER THAN THE DEPOSITARY OR ITS NOMINEE ONLY IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE AND MAY NOT BE TRANSFERRED EXCEPT AS A WHOLE BY THE DEPOSITARY TO A NOMINEE OF THE DEPOSITARY OR BY A NOMINEE OF THE DEPOSITARY TO THE DEPOSITARY OR ANOTHER NOMINEE OF THE DEPOSITARY.

The provisions of Clauses (1), (2), (3) and (4) below shall apply only to Global Securities:

(1) Each Global Security authenticated under the Indenture shall be registered in the name of the Depositary designated for such Global Security or a nominee thereof and delivered to such Depositary or a nominee thereof or custodian therefor, and each such Global Security shall constitute a single Security for all purposes of the Indenture.

(2) Notwithstanding any other provision in the Indenture, no Global Security may be exchanged in whole or in part for Securities registered, and no transfer of a Global Security in whole or in part may be registered, in the name of any Person other than the Depositary for such Global Security or a nominee thereof unless (A) the Company has notified the Trustee that the Depositary is unwilling or unable to continue as Depositary for such Global Security, the Depositary defaults in the performance of its duties as Depositary, or the Depositary has ceased to be a clearing agency registered under the Exchange Act, in each case, unless the Company has approved a successor Depositary

within 90 days, (B) the Company in its sole discretion determines that such Global Security will be so exchangeable or transferable or (C) there shall exist such circumstances, if any, in addition to or in lieu of the foregoing as have been specified for this purpose as contemplated by the Indenture.

(3) Subject to Clause (2) above, any exchange of a Global Security for other Securities may be made in whole or in part, and all Securities issued in exchange for a Global Security or any portion thereof shall be registered in such names as the Depositary for such Global Security shall direct.

(4) Every Security authenticated and delivered upon registration of transfer of, or in exchange for or in lieu of, a Global Security or any portion thereof, whether pursuant to Sections 304, 305, 306, 507 or 1406 of the Indenture or otherwise, shall be authenticated and delivered in the form of, and shall be, a Global Security, unless such Security is registered in the name of a Person other than the Depositary for such Global Security or a nominee thereof.

(18) Not applicable.

(19) Not applicable.

(20) For purposes of the Bonds, “Business Day” shall mean any day, other than Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York, New York.

(21) Not applicable.

(22) The Bonds shall have such other terms and provisions as are provided in the forms thereof attached hereto as Exhibit A and shall be issued in substantially such forms.

2. The undersigned has read all of the covenants and conditions contained in the Indenture, and the definitions in the Indenture relating thereto, relating to the authentication, delivery and issuance of the Bonds and the execution and delivery of the Thirty-Second Supplemental Indenture and in respect of compliance with which this certificate is made.

3. The statements contained in this certificate are based upon the familiarity of the undersigned with the Indenture, the documents accompanying this certificate, and upon discussions by the undersigned with officers and employees of the Company familiar with the matters set forth herein.

4. In the opinion of the undersigned, she has made such examination or investigation as is necessary to enable her to express an informed opinion as to whether or not such covenants and conditions have been complied with.

5. In the opinion of the undersigned, such conditions and covenants have been complied with.

6. To my knowledge, no Event of Default has occurred and is continuing.

7. The execution of the Thirty-Second Supplemental Indenture, dated as of the date hereof, between the Company and the Trustee is authorized or permitted by the Indenture.

8. With respect to Section 403(2)(B) of the Indenture, General Mortgage Bonds, due August 1, 2022, having an aggregate principal amount of $300,000,000 out of an aggregate principal amount of $300,000,000 remaining from the $300,000,000 original aggregate principal amount (the “Retired Mortgage Bonds”), have heretofore been authenticated and delivered and as of the date of this certificate, constitute Retired Securities. $300,000,000 aggregate principal amount of such Retired Mortgage Bonds are the basis for the authentication and delivery of $300,000,000 aggregate principal amount of the Series AJ Mortgage Bonds.

9. With respect to Section 402(2)(B) of the Indenture, Property Additions of $6,342,703,430.36 are the basis for authentication and delivery of $500,000,000 aggregate principal amount of the Series AI Mortgage Bonds.

10. The First Mortgage Collateralization Date has not occurred.

11. No certificate of an Independent Accountant pursuant to Section 104 of the Indenture is required in connection with the authentication and delivery of the Bonds because (i) the Net Earnings Certificate covers a period different from that required to be covered by annual reports required to be filed by the Company and (ii) an Independent Accountant has provided the Company with a letter addressed to the Company containing the results of procedures on financial information included in the Net Earnings Certificate that are agreed upon by the Authorized Officer signing the Net Earnings Certificate.

12. Pursuant to the resolutions adopted by the Sole Manager of the Company by written consent on September 2, 2022, Jacqueline M. Richert, Vice President, Investor Relations & Treasurer, has been named an Authorized Officer, as defined under the Indenture, including for purposes of executing the Net Earnings Certificate.

IN WITNESS WHEREOF, the undersigned has executed this Officer’s Certificate as of the date first written above.

/s/ Jacqueline M. Richert
Jacqueline M. Richert
Vice President, Investor Relations & Treasurer

Acknowledged and Received as
of the date first written above

THE BANK OF NEW YORK

MELLON TRUST COMPANY,

NATIONAL ASSOCIATION,

As Trustee

/s/ April Bradley
April Bradley

Vice President

EXHIBIT A

FORM OF BONDS

Unless this certificate is presented by an authorized representative of The Depository Trust Company, a New York corporation (“DTC”), to CenterPoint Energy Houston Electric, LLC or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
4.45% General Mortgage Bonds, Series AI, due 2032


Original Interest Accrual Date: September 15, 2022 Stated Maturity: October 1, 2032 Interest Rate: 4.45% Interest Payment Dates: April 1 and October 1 Regular Record Dates: March 15 and September 15 immediately preceding the respective Interest Payment Date			Redeemable: Yes [X] No [ ] Redemption Date: At any time. Redemption Price: Prior to July 1, 2032 at a redemption price equal to the greater of (i)(a) the sum of the present values of the remaining scheduled payments of principal and interest on this Security or the portion thereof to be redeemed discounted to the Redemption Date (assuming this Security matured on the Par Call Date) on a semiannual basis at the Treasury Rate plus 20 basis points, less (b) interest accrued to the Redemption Date, and (ii) 100% of the principal amount of this Security (or such portion to be redeemed); plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date; or on or after July 1, 2032, at a redemption price equal to 100% of the principal amount of this Security or the portion thereof to be redeemed plus accrued and unpaid interest thereon to, but excluding, the Redemption Date.

This Security is not an Original Issue Discount Security
within the meaning of the within-mentioned Indenture.
_____________________________

Principal Amount Registered No. T-1
$500,000,000* CUSIP 15189X AZ1

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC, a limited liability company duly organized and existing under the laws of the State of Texas (herein called the “Company,” which term includes any successor under the Indenture referred to below), for value received, hereby promises to pay to

***CEDE & Co.***

*Reference is made to Schedule A attached hereto with respect to decreases and increases in the aggregate principal amount of Securities evidenced hereby.

, or its registered assigns, the principal sum of FIVE HUNDRED MILLION DOLLARS, on the Stated Maturity specified above, and to pay interest thereon from the Original Interest Accrual Date specified above or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on the Interest Payment Dates specified above in each year, commencing on April 1, 2023, and at Maturity, at the Interest Rate per annum specified above, until the principal hereof is paid or duly provided for. The interest so payable, and paid or duly provided for, on any Interest Payment Date shall, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date specified above (whether or not a Business Day) next preceding such Interest Payment Date. Notwithstanding the foregoing, interest payable at Maturity shall be paid to the Person to whom principal shall be paid. Except as otherwise provided in said Indenture, any such interest not so paid or duly provided for shall forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice of which shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Payment of the principal of and premium, if any, on this Security and interest hereon at Maturity shall be made upon presentation of this Security at the office of the Corporate Trust Administration of The Bank of New York Mellon Trust Company, National Association, located in New York, New York or at such other office or agency as may be designated for such purpose by the Company from time to time. Payment of interest on this Security (other than interest at Maturity) shall be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register, except that if such Person shall be a securities depositary, such payment may be made by such other means in lieu of check, as shall be agreed upon by the Company, the Trustee and such Person. Payment of the principal of and premium, if any, and interest on this Security, as aforesaid, shall be made in such coin or currency of the United States of America as at the time of payment shall be legal tender for the payment of public and private debts.

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and issuable in one or more series under and equally secured by a General Mortgage Indenture, dated as of October 10, 2002, as supplemented and amended (such Indenture as originally executed and delivered and as supplemented or amended from time to time thereafter, together with any constituent instruments establishing the terms of particular Securities, being herein called the “Indenture”), between the Company and The Bank of New York Mellon Trust Company, National Association (successor in trust to JPMorgan Chase

Bank), trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the property mortgaged, pledged and held in trust, the nature and extent of the security and the respective rights, limitations of rights, duties and immunities of the Company, the Trustee and the Holders of the Securities thereunder and of the terms and conditions upon which the Securities are, and are to be, authenticated and delivered and secured. The acceptance of this Security shall be deemed to constitute the consent and agreement by the Holder hereof to all of the terms and provisions of the Indenture. This Security is one of the series designated above.

If any Interest Payment Date, any Redemption Date or the Stated Maturity shall not be a Business Day (as hereinafter defined), payment of the amounts due on this Security on such date may be made on the next succeeding Business Day; and, if such payment is made or duly provided for on such Business Day, no interest shall accrue on such amounts for the period from and after such Interest Payment Date, Redemption Date or Stated Maturity, as the case may be, to such Business Day. Interest will be computed on the basis of a 360-day year of twelve 30-day months.

Prior to July 1, 2032 (the “Par Call Date”), the Company may redeem this Security, in whole or in part, at any time and from time to time, at a redemption price (expressed as a percentage of principal amount and rounded to three decimal places) equal to the greater of:

•(1)(a) the sum of the present values of the remaining scheduled payments of principal and interest on this Security (or such portion to be redeemed) discounted to the Redemption Date (assuming this Security matured on the Par Call Date) on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 20 basis points; less (b) interest accrued to the Redemption Date; and

•(2) 100% of the principal amount of this Security (or such portion to be redeemed);

plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date.

On or after the Par Call Date, the Company may redeem this Security, in whole or in part, at any time and from time to time, at a redemption price equal to 100% of the principal amount of this Security (or such portion to be redeemed) plus accrued and unpaid interest thereon to, but excluding, the Redemption Date. The Trustee shall have no responsibility for the calculation of such amount.

“Treasury Rate” means, with respect to any Redemption Date, the yield determined by the Company in accordance with the following two paragraphs.

The Treasury Rate shall be determined by the Company after 4:15 p.m., New York City time (or after such time as yields on U.S. government securities are posted daily by the Board of Governors of the Federal Reserve System), on the third Business Day preceding the Redemption Date based upon the yield or yields for the most recent day that appear after such time on such day in the most recent statistical release published by the Board of Governors of the Federal Reserve System designated as “Selected Interest Rates (Daily) - H.15” (or any successor designation or publication) (“H.15”) under the caption “U.S. government securities–Treasury constant maturities–Nominal” (or any successor caption or heading) (“H.15 TCM”). In determining the Treasury Rate, the Company shall select, as applicable: (1) the yield for the Treasury constant maturity on H.15 exactly equal to the period from the Redemption Date to the Par Call Date (the “Remaining Life”); or (2) if there is no such Treasury constant maturity on H.15 exactly equal to the Remaining Life, the two yields – one yield corresponding to the Treasury constant maturity on H.15 immediately shorter than and one yield corresponding to the

Treasury constant maturity on H.15 immediately longer than the Remaining Life – and shall interpolate to the Par Call Date on a straight-line basis (using the actual number of days) using such yields and rounding the result to three decimal places; or (3) if there is no such Treasury constant maturity on H.15 shorter than or longer than the Remaining Life, the yield for the single Treasury constant maturity on H.15 closest to the Remaining Life. For purposes of this paragraph, the applicable Treasury constant maturity or maturities on H.15 shall be deemed to have a maturity date equal to the relevant number of months or years, as applicable, of such Treasury constant maturity from the Redemption Date.

If on the third Business Day preceding the Redemption Date H.15 TCM or any successor designation or publication is no longer published, the Company shall calculate the Treasury Rate based on the rate per annum equal to the semi-annual equivalent yield to maturity at 11:00 a.m., New York City time, on the second Business Day preceding such Redemption Date of the United States Treasury security maturing on, or with a maturity that is closest to, the Par Call Date, as applicable. If there is no United States Treasury security maturing on the Par Call Date but there are two or more United States Treasury securities with a maturity date equally distant from the Par Call Date, one with a maturity date preceding the Par Call Date and one with a maturity date following the Par Call Date, the Company shall select the United States Treasury security with a maturity date preceding the Par Call Date. If there are two or more United States Treasury securities maturing on the Par Call Date or two or more United States Treasury securities meeting the criteria of the preceding sentence, the Company shall select from among these two or more United States Treasury securities the United States Treasury security that is trading closest to par based upon the average of the bid and asked prices for such United States Treasury securities at 11:00 a.m., New York City time. In determining the Treasury Rate in accordance with the terms of this paragraph, the semi-annual yield to maturity of the applicable United States Treasury security shall be based upon the average of the bid and asked prices (expressed as a percentage of principal amount) at 11:00 a.m., New York City time, of such United States Treasury security, and rounded to three decimal places.

The Company’s actions and determinations in determining the redemption price shall be conclusive and binding for all purposes, absent manifest error.

The Trustee, at the written direction of the Company, will send a notice of redemption to each Holder of Securities to be redeemed by first-class mail (or in accordance with the procedures of The Depository Trust Company with respect to Securities registered in the name of Cede & Co.) at least 10 and not more than 60 days prior to the date fixed for redemption. Unless the Company defaults on payment of the redemption price, interest will cease to accrue on the Securities or portions thereof called for redemption on the Redemption Date. If fewer than all of the Securities of this series are to be redeemed, not more than 60 days prior to the Redemption Date, the particular Securities of this series or portions thereof for redemption will be selected from the outstanding Securities of this series not previously called by such method as the Trustee deems fair and appropriate. The Trustee may select for redemption Securities of this series and portions of Securities of this series in amounts of $2,000 or whole multiples of $1,000. In the case of a partial redemption of Securities registered in the name of Cede & Co, the Securities to be redeemed will be determined in accordance with the procedures of The Depository Trust Company.

The Indenture permits, with certain exceptions as therein provided, the Trustee to enter into one or more supplemental indentures for the purpose of adding any provisions to, or changing in any manner or eliminating any of the provisions of, the Indenture with the consent of the Holders of not less than a majority in aggregate principal amount of the Securities of all series then Outstanding under the Indenture, considered as one class; provided, however, that if there shall

be Securities of more than one series Outstanding under the Indenture and if a proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such series, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all series so directly affected, considered as one class, shall be required; and provided, further, that if the Securities of any series shall have been issued in more than one Tranche and if the proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such Tranches, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all Tranches so directly affected, considered as one class, shall be required; and provided, further, that the Indenture permits the Trustee to enter into one or more supplemental indentures for limited purposes without the consent of any Holders of Securities. The Indenture also contains provisions permitting the Holders of a majority in principal amount of the Securities then Outstanding, on behalf of the Holders of all Securities, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in the Indenture and subject to certain limitations therein set forth, this Security or any portion of the principal amount hereof will be deemed to have been paid for all purposes of the Indenture and to be no longer Outstanding thereunder, and, at the election of the Company, the Company’s entire indebtedness in respect thereof will be satisfied and discharged, if there has been irrevocably deposited with the Trustee or any Paying Agent (other than the Company), in trust, money in an amount which will be sufficient and/or Eligible Obligations, the principal of and interest on which when due, without regard to any reinvestment thereof, will provide moneys which, together with moneys so deposited, will be sufficient to pay when due the principal of and interest on this Security when due.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the Corporate Trust Office of The Bank of New York Mellon Trust Company, National Association in New York, New York, or such other office or agency as may be designated by the Company from time to time, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series of authorized denominations and of like tenor and aggregate principal amount, will be issued to the designated transferee or transferees.

The Securities of this series are issuable only as registered Securities, without coupons, and in minimum denominations of $2,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of the same series and Tranche, of any authorized denominations, as requested by the Holder surrendering the same, and of like tenor upon surrender of the Security or Securities to be exchanged at the office of The Bank of New York Mellon Trust Company, National Association in New York, New York, or such other office or agency as may be designated by the Company from time to time.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the absolute owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

The Securities are not entitled to the benefit of any sinking fund.

As used herein, “Business Day” shall mean any day, other than Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York, New York. All other terms used in this Security which are defined in the Indenture shall have the meanings assigned to them in the Indenture.

As provided in the Indenture, no recourse shall be had for the payment of the principal of or premium, if any, or interest on any Securities, or any part thereof, or for any claim based thereon or otherwise in respect thereof, or of the indebtedness represented thereby, or upon any obligation, covenant or agreement under the Indenture, against, and no personal liability whatsoever shall attach to, or be incurred by, any incorporator, member, manager, stockholder, officer, director or employee, as such, past, present or future of the Company or of any predecessor or successor corporation (either directly or through the Company or a predecessor or successor corporation), whether by virtue of any constitutional provision, statute or rule of law, or by the enforcement of any assessment or penalty or otherwise; it being expressly agreed and understood that the Indenture and all the Securities are solely corporate obligations and that any such personal liability is hereby expressly waived and released as a condition of, and as part of the consideration for, the execution of the Indenture and the issuance of the Securities.

Unless the certificate of authentication hereon has been executed by the Trustee or an Authenticating Agent by manual or electronic signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

[The remainder of this page is intentionally left blank.]

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.


Attest: ____________________________ Vincent A. Mercaldi Secretary			CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC By: Kara G. Ryan Vice President and Chief Accounting Officer

(SEAL)

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Date of Authentication: ______________, 2022

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee

By:

SCHEDULE A

The initial aggregate principal amount of Securities evidenced by the Certificate to which this Schedule is attached is $500,000,000. The notations on the following table evidence decreases and increases in the aggregate principal amount of Securities evidenced by such Certificate.

Aggregate Principal

Amount of Securities

Decrease in Aggregate

Increase in Aggregate

Remaining After

Notation by

Date of

Principal Amount of

Such Decrease or

Security

Adjustment

Securities

Increase

Registrar

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
4.85% General Mortgage Bonds, Series AJ, due 2052


Original Interest Accrual Date: September 15, 2022 Stated Maturity: October 1, 2052 Interest Rate: 4.85% Interest Payment Dates: April 1 and October 1 Regular Record Dates: March 15 and September 15 immediately preceding the respective Interest Payment Date			Redeemable: Yes [X] No [ ] Redemption Date: At any time. Redemption Price: Prior to April 1, 2052 at a redemption price equal to the greater of (i)(a) the sum of the present values of the remaining scheduled payments of principal and interest on this Security or the portion thereof to be redeemed discounted to the Redemption Date (assuming this Security matured on the Par Call Date) on a semiannual basis at the Treasury Rate plus 25 basis points, less (b) interest accrued to the Redemption Date, and (ii) 100% of the principal amount of this Security (or such portion to be redeemed); plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date; or on or after April 1, 2052, at a redemption price equal to 100% of the principal amount of this Security or the portion thereof to be redeemed plus accrued and unpaid interest thereon to, but excluding, the Redemption Date.

This Security is not an Original Issue Discount Security
within the meaning of the within-mentioned Indenture.
_____________________________

Principal Amount Registered No. T-1
$300,000,000* CUSIP 15189X BA5

***CEDE & Co.***

*Reference is made to Schedule A attached hereto with respect to decreases and increases in the aggregate principal amount of Securities evidenced hereby.

, or its registered assigns, the principal sum of THREE HUNDRED MILLION DOLLARS, on the Stated Maturity specified above, and to pay interest thereon from the Original Interest Accrual Date specified above or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on the Interest Payment Dates specified above in each year, commencing on April 1, 2023, and at Maturity, at the Interest Rate per annum specified above, until the principal hereof is paid or duly provided for. The interest so payable, and paid or duly provided for, on any Interest Payment Date shall, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date specified above (whether or not a Business Day) next preceding such Interest Payment Date. Notwithstanding the foregoing, interest payable at Maturity shall be paid to the Person to whom principal shall be paid. Except as otherwise provided in said Indenture, any such interest not so paid or duly provided for shall forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice of which shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Prior to April 1, 2052 (the “Par Call Date”), the Company may redeem this Security, in whole or in part, at any time and from time to time, at a redemption price (expressed as a percentage of principal amount and rounded to three decimal places) equal to the greater of:

•(1)(a) the sum of the present values of the remaining scheduled payments of principal and interest on this Security (or such portion to be redeemed) discounted to the Redemption Date (assuming this Security matured on the Par Call Date) on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 25 basis points; less (b) interest accrued to the Redemption Date; and

•(2) 100% of the principal amount of this Security (or such portion to be redeemed);

plus, in each case, accrued and unpaid interest thereon to, but excluding, the Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the yield determined by the Company in accordance with the following two paragraphs.

If on the third Business Day preceding the Redemption Date H.15 TCM or any successor designation or publication is no longer published, the Company shall calculate the Treasury Rate based on the rate per annum equal to the semi-annual equivalent yield to maturity at 11:00 a.m., New York City time, on the second Business Day preceding such Redemption Date of the United States Treasury security maturing on, or with a maturity that is closest to, the Par Call Date, as applicable. If there is no United States Treasury security maturing on the Par Call Date but there are two or more United States Treasury securities with a maturity date equally distant from the Par Call Date, one with a maturity date preceding the Par Call Date and one with a maturity date following the Par Call Date, the Company shall select the United States Treasury security with a maturity date preceding the Par Call Date. If there are two or more United States Treasury securities maturing on the Par Call Date or two or more United States Treasury securities meeting the criteria of the preceding sentence, the Company shall select from among these two or more United States Treasury securities the United States Treasury security that is trading closest to par based upon the average of the bid and asked prices for such United States Treasury securities at 11:00 a.m., New York City time. In determining the Treasury Rate in accordance with the terms of this paragraph, the semi-annual yield to maturity of the applicable United States Treasury security shall be based upon the average of the bid and asked prices (expressed as a percentage of principal amount) at 11:00 a.m., New York City time, of such United States Treasury security, and rounded to three decimal places.

The Company’s actions and determinations in determining the redemption price shall be conclusive and binding for all purposes, absent manifest error.

supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such series, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all series so directly affected, considered as one class, shall be required; and provided, further, that if the Securities of any series shall have been issued in more than one Tranche and if the proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such Tranches, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all Tranches so directly affected, considered as one class, shall be required; and provided, further, that the Indenture permits the Trustee to enter into one or more supplemental indentures for limited purposes without the consent of any Holders of Securities. The Indenture also contains provisions permitting the Holders of a majority in principal amount of the Securities then Outstanding, on behalf of the Holders of all Securities, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is

registered as the absolute owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

The Securities are not entitled to the benefit of any sinking fund.

[The remainder of this page is intentionally left blank.]

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.


Attest: ____________________________ Vincent A. Mercaldi Secretary			CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC By: Kara G. Ryan Vice President and Chief Accounting Officer

(SEAL)

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Date of Authentication: ______________, 2022

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee

By:

SCHEDULE A

The initial aggregate principal amount of Securities evidenced by the Certificate to which this Schedule is attached is $300,000,000. The notations on the following table evidence decreases and increases in the aggregate principal amount of Securities evidenced by such Certificate.

Aggregate Principal

Amount of Securities

Decrease in Aggregate

Increase in Aggregate

Remaining After

Notation by

Date of

Principal Amount of

Such Decrease or

Security

Adjustment

Securities

Increase

Registrar

Document

Exhibit 31.1.1

CERTIFICATIONS

I, David J. Lesar, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy, Inc.;

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(s) 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(s) 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 1, 2022


			/s/ David J. Lesar
			David J. Lesar
			President and Chief Executive Officer

Document

Exhibit 31.1.2

CERTIFICATIONS

I, Scott E. Doyle, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Houston Electric, LLC;

(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 1, 2022


			/s/ Scott E. Doyle
			Scott E. Doyle
			Manager, President and Chief Executive Officer

Document

Exhibit 31.1.3

CERTIFICATIONS

I, Scott E. Doyle, certify that:

1. I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Resources Corp.;

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(s) 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:

(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(s) 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 1, 2022


/s/ Scott E. Doyle
Scott E. Doyle
President and Chief Executive Officer

Document

Exhibit 31.2.1

CERTIFICATIONS

I, Jason P. Wells, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy, Inc.;

(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 1, 2022


			/s/ Jason P. Wells
			Jason P. Wells
			Executive Vice President and Chief Financial Officer

Document

Exhibit 31.2.2

CERTIFICATIONS

I, Jason P. Wells, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Houston Electric, LLC;

(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 1, 2022


			/s/ Jason P. Wells
			Jason P. Wells
			Executive Vice President and Chief Financial Officer

Document

Exhibit 31.2.3

CERTIFICATIONS

I, Jason P. Wells, certify that:

1. I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Resources Corp.;

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;

(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 1, 2022


			/s/ Jason P. Wells
			Jason P. Wells
			Executive Vice President and Chief Financial Officer

Document

Exhibit 32.1.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, David J. Lesar, Chief Executive Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ David J. Lesar
David J. Lesar
President and Chief Executive Officer
November 1, 2022

Document

Exhibit 32.1.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott E. Doyle, Chief Executive Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ Scott E. Doyle
Scott E. Doyle
Manager, President and Chief Executive Officer
November 1, 2022

Document

Exhibit 32.1.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Resources Corp. (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott E. Doyle, Chief Executive Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ Scott E. Doyle
Scott E. Doyle
President and Chief Executive Officer
November 1, 2022

Document

Exhibit 32.2.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Jason P. Wells, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ Jason P. Wells
Jason P. Wells
Executive Vice President and Chief Financial Officer
November 1, 2022

Document

Exhibit 32.2.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Jason P. Wells, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ Jason P. Wells
Jason P. Wells
Executive Vice President and Chief Financial Officer
November 1, 2022

Document

Exhibit 32.2.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Resources Corp. (the “Company”) on Form 10-Q for the quarter ended September 30, 2022 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Jason P. Wells, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

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

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


/s/ Jason P. Wells
Jason P. Wells
Executive Vice President and Chief Financial Officer
November 1, 2022