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					Three Months Ended				Six Months Ended
		September 30,				September 30,					June 30,				June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions, except per share amounts)									(in millions, except per share amounts)
Revenues:	Revenues:									Revenues:
Utility revenues	Utility revenues	$	1,829	$	1,661	$	6,400	$	5,797	Utility revenues	$	1,789	$	1,862	$	4,506	$	4,571
Non-utility revenues	Non-utility revenues	74		88		210		241		Non-utility revenues	86		82		148		136
Total	Total	1,903		1,749		6,610		6,038		Total	1,875		1,944		4,654		4,707
Expenses:	Expenses:									Expenses:
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power	349		223		1,860		1,416		Utility natural gas, fuel and purchased power	280		413		1,358		1,511
Non-utility cost of revenues, including natural gas	Non-utility cost of revenues, including natural gas	52		61		143		159		Non-utility cost of revenues, including natural gas	57		56		97		91
Operation and maintenance	Operation and maintenance	670		709		2,020		2,055		Operation and maintenance	679		662		1,342		1,350
Depreciation and amortization	Depreciation and amortization	329		353		974		987		Depreciation and amortization	349		327		668		645
Taxes other than income taxes	Taxes other than income taxes	119		125		401		394		Taxes other than income taxes	130		135		268		282

Total	Total	1,519		1,471		5,398		5,011		Total	1,495		1,593		3,733		3,879
Operating Income	Operating Income	384		278		1,212		1,027		Operating Income	380		351		921		828
Other Income (Expense):	Other Income (Expense):									Other Income (Expense):
Gain (loss) on equity securities	Gain (loss) on equity securities	(206)		(12)		(284)		40		Gain (loss) on equity securities	(31)		(61)		7		(78)
Gain (loss) on indexed debt securities	Gain (loss) on indexed debt securities	210		11		381		(40)		Gain (loss) on indexed debt securities	34		65		(5)		171
Gain on sale		—		8		303		8
Gain (loss) on sale										Gain (loss) on sale	(12)		—		(12)		303
Interest expense and other finance charges	Interest expense and other finance charges	(116)		(114)		(375)		(380)		Interest expense and other finance charges	(165)		(106)		(313)		(259)
Interest expense on Securitization Bonds	Interest expense on Securitization Bonds	(3)		(5)		(11)		(16)		Interest expense on Securitization Bonds	(2)		(4)		(4)		(8)

Other income, net		8		17		25		54

Other income (expense), net										Other income (expense), net	13		(1)		26		17
Total	Total	(107)		(95)		39		(334)		Total	(163)		(107)		(301)		146
Income from Continuing Operations Before Income Taxes		277		183		1,251		693
Income Before Income Taxes										Income Before Income Taxes	217		244		620		974
Income tax expense	Income tax expense	75		33		328		63		Income tax expense	99		54		177		253
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	Net Income	202		218		923		832		Net Income	118		190		443		721
Income allocated to preferred shareholders	Income allocated to preferred shareholders	13		23		37		82		Income allocated to preferred shareholders	12		11		24		24
Income Available to Common Shareholders	Income Available to Common Shareholders	$	189	$	195	$	886	$	750	Income Available to Common Shareholders	$	106	$	179	$	419	$	697

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	Basic Earnings Per Common Share	0.30		0.32		1.41		1.29		Basic Earnings Per Common Share	0.17		0.28		0.66		1.11
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	Diluted Earnings Per Common Share	$	0.30	$	0.32	$	1.40	$	1.25	Diluted Earnings Per Common Share	$	0.17	$	0.28	$	0.66	$	1.10

Weighted Average Common Shares Outstanding, Basic	Weighted Average Common Shares Outstanding, Basic	630		605		629		581		Weighted Average Common Shares Outstanding, Basic	631		629		631		629
Weighted Average Common Shares Outstanding, Diluted	Weighted Average Common Shares Outstanding, Diluted	633		609		633		601		Weighted Average Common Shares Outstanding, Diluted	633		632		633		631

See Combined Notes to Interim Condensed Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)


		Three Months Ended				Nine Months Ended					Three Months Ended				Six Months Ended
		September 30,				September 30,					June 30,				June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Net Income	Net Income	$	202	$	218	$	923	$	832	Net Income	$	118	$	190	$	443	$	721
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
Other comprehensive income (loss):										Other comprehensive income (loss):
Adjustment to pension and other postretirement plans (net of tax expense (benefit) of $-0-, $4, $-0- and $4)										Adjustment to pension and other postretirement plans (net of tax expense (benefit) of $-0-, $4, $-0- and $4)	—		(23)		(1)		(22)

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

Other comprehensive income from unconsolidated affiliates (net of tax of $-0-, $-0-, $-0- and $-0-)		—		—		—		2

Total	Total	2		5		(19)		10		Total	—		(23)		(1)		(21)
Comprehensive income	Comprehensive income	204		223		904		842		Comprehensive income	118		167		442		700
Income allocated to preferred shareholders	Income allocated to preferred shareholders	13		23		37		82		Income allocated to preferred shareholders	12		11		24		24
Comprehensive income available to common shareholders	Comprehensive income available to common shareholders	$	191	$	200	$	867	$	760	Comprehensive income available to common shareholders	$	106	$	156	$	418	$	676

See Combined Notes to Interim Condensed Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents ($110 and $92 related to VIEs, respectively)		$	114	$	230
Cash and cash equivalents ($63 and $75 related to VIEs, respectively)						Cash and cash equivalents ($63 and $75 related to VIEs, respectively)	$	214	$	74
Investment in equity securities	Investment in equity securities	452		1,439		Investment in equity securities	517		510

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
Accounts receivable ($25 and $22 related to VIEs, respectively), less allowance for credit losses of $41 and $38, respectively						Accounts receivable ($25 and $22 related to VIEs, respectively), less allowance for credit losses of $41 and $38, respectively	638		889
Accrued unbilled revenues, less allowance for credit losses of $1 and $4, respectively						Accrued unbilled revenues, less allowance for credit losses of $1 and $4, respectively	289		764

Natural gas and coal inventory	Natural gas and coal inventory	308		186		Natural gas and coal inventory	79		241
Materials and supplies	Materials and supplies	574		422		Materials and supplies	650		635
Non-trading derivative assets	Non-trading derivative assets	29		9		Non-trading derivative assets	1		10
Taxes receivable	Taxes receivable	—		1		Taxes receivable	18		20
Current assets held for sale		—		2,338

Regulatory assets	Regulatory assets	1,377		1,395		Regulatory assets	241		1,385
Prepaid expenses and other current assets ($12 and $19 related to VIEs, respectively)		141		132
Prepaid expenses and other current assets ($14 and $13 related to VIEs, respectively)						Prepaid expenses and other current assets ($14 and $13 related to VIEs, respectively)	155		171
Total current assets	Total current assets	4,083		7,355		Total current assets	2,802		4,699
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Property, plant and equipment	Property, plant and equipment	36,478		33,673		Property, plant and equipment	38,774		37,728
Less: accumulated depreciation and amortization	Less: accumulated depreciation and amortization	10,568		10,189		Less: accumulated depreciation and amortization	10,320		10,585
Property, plant and equipment, net	Property, plant and equipment, net	25,910		23,484		Property, plant and equipment, net	28,454		27,143
Other Assets:	Other Assets:					Other Assets:
Goodwill	Goodwill	4,294		4,294		Goodwill	4,160		4,294
Regulatory assets ($265 and $420 related to VIEs, respectively)		2,212		2,321
Regulatory assets ($497 and $229 related to VIEs, respectively)						Regulatory assets ($497 and $229 related to VIEs, respectively)	2,495		2,193

Non-trading derivative assets	Non-trading derivative assets	6		5		Non-trading derivative assets	—		2

Other non-current assets	Other non-current assets	214		220		Other non-current assets	186		215
Total other assets	Total other assets	6,726		6,840		Total other assets	6,841		6,704
Total Assets	Total Assets	$	36,719	$	37,679	Total Assets	$	38,097	$	38,546

See Combined Notes to Interim Condensed Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(Unaudited)


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in millions, except par value and shares)					(in millions, except par value and shares)
LIABILITIES AND SHAREHOLDERS’ EQUITY	LIABILITIES AND SHAREHOLDERS’ EQUITY					LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:
Short-term borrowings	Short-term borrowings	$	514	$	7	Short-term borrowings	$	2	$	511
Current portion of VIE Securitization Bonds long-term debt	Current portion of VIE Securitization Bonds long-term debt	153		220		Current portion of VIE Securitization Bonds long-term debt	170		156
Indexed debt, net	Indexed debt, net	8		10		Indexed debt, net	6		7
Current portion of other long-term debt	Current portion of other long-term debt	1,478		308		Current portion of other long-term debt	756		1,346
Indexed debt securities derivative	Indexed debt securities derivative	522		903		Indexed debt securities derivative	583		578
Accounts payable	Accounts payable	1,028		1,196		Accounts payable	832		1,352

Taxes accrued	Taxes accrued	273		378		Taxes accrued	176		298
Interest accrued	Interest accrued	118		136		Interest accrued	203		159
Dividends accrued	Dividends accrued	113		131		Dividends accrued	—		144
Customer deposits	Customer deposits	109		111		Customer deposits	109		110
Non-trading derivative liabilities		—		2

Current liabilities held for sale		—		562

Other current liabilities	Other current liabilities	295		323		Other current liabilities	347		452
Total current liabilities	Total current liabilities	4,611		4,287		Total current liabilities	3,184		5,113
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes, net	Deferred income taxes, net	3,974		3,904		Deferred income taxes, net	4,036		3,986
Non-trading derivative liabilities		—		12

Benefit obligations	Benefit obligations	578		511		Benefit obligations	555		547
Regulatory liabilities	Regulatory liabilities	3,295		3,153		Regulatory liabilities	3,091		3,245

Other non-current liabilities	Other non-current liabilities	835		836		Other non-current liabilities	833		774
Total other liabilities	Total other liabilities	8,682		8,416		Total other liabilities	8,515		8,552
Long-term Debt:	Long-term Debt:					Long-term Debt:
VIE Securitization Bonds, net	VIE Securitization Bonds, net	240		317		VIE Securitization Bonds, net	408		161
Other long-term debt, net	Other long-term debt, net	13,195		15,241		Other long-term debt, net	15,624		14,675
Total long-term debt, net	Total long-term debt, net	13,435		15,558		Total long-term debt, net	16,032		14,836
Commitments and Contingencies (Note 13)	Commitments and Contingencies (Note 13)					Commitments and Contingencies (Note 13)
Temporary Equity (Note 18)	Temporary Equity (Note 18)	2		3		Temporary Equity (Note 18)	—		3
Shareholders’ Equity:	Shareholders’ Equity:					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)	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		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
Common stock, $0.01 par value, 1,000,000,000 shares authorized, 631,073,571 shares and 629,535,631 shares outstanding, respectively						Common stock, $0.01 par value, 1,000,000,000 shares authorized, 631,073,571 shares and 629,535,631 shares outstanding, respectively	6		6
Additional paid-in capital	Additional paid-in capital	8,557		8,529		Additional paid-in capital	8,570		8,568
Retained earnings	Retained earnings	719		154		Retained earnings	1,032		709
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(83)		(64)		Accumulated other comprehensive loss	(32)		(31)
Total shareholders’ equity	Total shareholders’ equity	9,989		9,415		Total shareholders’ equity	10,366		10,042
Total Liabilities and Shareholders’ Equity	Total Liabilities and Shareholders’ Equity	$	36,719	$	37,679	Total Liabilities and Shareholders’ Equity	$	38,097	$	38,546

See Combined Notes to Interim Condensed Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
		(in millions)					(in millions)
Cash Flows from Operating Activities:	Cash Flows from Operating Activities:					Cash Flows from Operating Activities:
Net income	Net income	$	923	$	832	Net income	$	443	$	721

Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	974		987		Depreciation and amortization	668		645

Deferred income taxes	Deferred income taxes	26		86		Deferred income taxes	22		23

Gain on divestitures		(303)		(8)
Loss (gain) on divestitures						Loss (gain) on divestitures	12		(303)
Loss (gain) on equity securities	Loss (gain) on equity securities	284		(40)		Loss (gain) on equity securities	(7)		78
Loss (gain) on indexed debt securities	Loss (gain) on indexed debt securities	(381)		40		Loss (gain) on indexed debt securities	5		(171)

Equity in earnings of unconsolidated affiliates		—		(258)
Distributions from unconsolidated affiliates		—		116

Pension contributions	Pension contributions	(6)		(59)		Pension contributions	(4)		(4)
Changes in other assets and liabilities:	Changes in other assets and liabilities:					Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	Accounts receivable and unbilled revenues, net	95		231		Accounts receivable and unbilled revenues, net	647		64

Inventory	Inventory	(224)		(104)		Inventory	142		15
Taxes receivable	Taxes receivable	1		68		Taxes receivable	2		(2)
Accounts payable	Accounts payable	(119)		(53)		Accounts payable	(403)		(132)

Net regulatory assets and liabilities	Net regulatory assets and liabilities	148		(2,309)		Net regulatory assets and liabilities	1,022		113

Other current assets and liabilities	Other current assets and liabilities	(199)		(25)		Other current assets and liabilities	(120)		(164)
Other non-current assets and liabilities	Other non-current assets and liabilities	34		(95)		Other non-current assets and liabilities	48		30
Other operating activities, net	Other operating activities, net	72		74		Other operating activities, net	5		65

Net cash provided by (used in) operating activities		1,325		(517)
Net cash provided by operating activities						Net cash provided by operating activities	2,482		978
Cash Flows from Investing Activities:	Cash Flows from Investing Activities:					Cash Flows from Investing Activities:
Capital expenditures	Capital expenditures	(3,079)		(2,148)		Capital expenditures	(2,259)		(1,880)

Proceeds from sale of marketable securities	Proceeds from sale of marketable securities	702		—		Proceeds from sale of marketable securities	—		702
Proceeds from divestitures		2,075		22
Proceeds from divestitures, net of cash divested						Proceeds from divestitures, net of cash divested	145		2,075

Other investing activities, net	Other investing activities, net	73		22		Other investing activities, net	(40)		45

Net cash used in investing activities		(229)		(2,104)
Net cash provided by (used in) investing activities						Net cash provided by (used in) investing activities	(2,154)		942
Cash Flows from Financing Activities:	Cash Flows from Financing Activities:					Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net		457		(27)
Decrease in short-term borrowings, net						Decrease in short-term borrowings, net	(14)		(43)
Payment of obligation for finance lease	Payment of obligation for finance lease	(218)		—		Payment of obligation for finance lease	—		(171)
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)
Payments of commercial paper, net						Payments of commercial paper, net	(920)		(1,226)
Proceeds from long-term debt and term loans						Proceeds from long-term debt and term loans	3,675		1,292
Payments of long-term debt and term loans, including make-whole premiums						Payments of long-term debt and term loans, including make-whole premiums	(2,613)		(1,187)

Payment of debt issuance costs	Payment of debt issuance costs	(26)		(38)		Payment of debt issuance costs	(28)		(17)

Payment of dividends on Common Stock	Payment of dividends on Common Stock	(328)		(278)		Payment of dividends on Common Stock	(240)		(214)
Payment of dividends on Preferred Stock	Payment of dividends on Preferred Stock	(48)		(106)		Payment of dividends on Preferred Stock	(24)		(24)

Other financing activities, net	Other financing activities, net	(7)		(6)		Other financing activities, net	(23)		(7)

Net cash provided by (used in) financing activities		(1,220)		2,610
Net Decrease in Cash, Cash Equivalents and Restricted Cash		(124)		(11)
Net cash used in financing activities						Net cash used in financing activities	(187)		(1,597)
Net Increase in Cash, Cash Equivalents and Restricted Cash						Net Increase in Cash, Cash Equivalents and Restricted Cash	141		323
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	Cash, Cash Equivalents and Restricted Cash at Beginning of Period	254		167		Cash, Cash Equivalents and Restricted Cash at Beginning of Period	91		254
Cash, Cash Equivalents and Restricted Cash at End of Period	Cash, Cash Equivalents and Restricted Cash at End of Period	$	130	$	156	Cash, Cash Equivalents and Restricted Cash at End of Period	$	232	$	577

See Combined Notes to Interim Condensed Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


		Three Months Ended September 30,						Nine Months Ended September 30,							Three Months Ended June 30,						Six Months Ended June 30,
		2022			2021			2022			2021				2023			2022			2023			2022
		Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount			Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
		(in millions of dollars and shares, except authorized shares and par value amounts)													(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	Cumulative Preferred Stock, $0.01 par value; authorized 20,000,000 shares													Cumulative Preferred Stock, $0.01 par value; authorized 20,000,000 shares
Balance, beginning of period	Balance, beginning of period	1	$	790	3	$	1,739	1	$	790	3	$	2,363	Balance, beginning of period	1	$	790	1	$	790	1	$	790	1	$	790

Conversion of Series B Preferred Stock and Series C Preferred Stock		—	—		(2)	(949)		—	—		(2)	(1,573)

Balance, end of period	Balance, end of period	1	790		1	790		1	790		1	790		Balance, end of period	1	790		1	790		1	790		1	790
Common Stock, $0.01 par value; authorized 1,000,000,000 shares	Common Stock, $0.01 par value; authorized 1,000,000,000 shares													Common Stock, $0.01 par value; authorized 1,000,000,000 shares
Balance, beginning of period	Balance, beginning of period	629	6		593	6		629	6		551	6		Balance, beginning of period	631	6		629	6		630	6		629	6
Issuances of Common Stock		—	—		36	—		—	—		77	—

Issuances related to benefit and investment plans	Issuances related to benefit and investment plans	—	—		—	—		—	—		1	—		Issuances related to benefit and investment plans	—	—		—	—		1	—		—	—
Balance, end of period	Balance, end of period	629	6		629	6		629	6		629	6		Balance, end of period	631	6		629	6		631	6		629	6
Additional Paid-in-Capital	Additional Paid-in-Capital													Additional Paid-in-Capital
Balance, beginning of period	Balance, beginning of period		8,544			7,553			8,529			6,914		Balance, beginning of period		8,558			8,532			8,568			8,529
Issuances of Common Stock, net of issuance costs			—			949			—			1,573

Issuances related to benefit and investment plans	Issuances related to benefit and investment plans		13			15			28			30		Issuances related to benefit and investment plans		12			12			2			15

Balance, end of period	Balance, end of period		8,557			8,517			8,557			8,517		Balance, end of period		8,570			8,544			8,570			8,544
Retained Earnings (Accumulated Deficit)
Retained Earnings														Retained Earnings
Balance, beginning of period	Balance, beginning of period		768			(343)			154			(845)		Balance, beginning of period		1,034			685			709			154
Net income	Net income		202			218			923			832		Net income		118			190			443			721
Common Stock dividends declared (see Note 18)	Common Stock dividends declared (see Note 18)		(227)			(202)			(334)			(297)		Common Stock dividends declared (see Note 18)		(120)			(107)			(120)			(107)
Preferred Stock dividends declared (see Note 18)			(24)			(41)			(24)			(58)

Balance, end of period	Balance, end of period		719			(368)			719			(368)		Balance, end of period		1,032			768			1,032			768
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss													Accumulated Other Comprehensive Loss
Balance, beginning of period	Balance, beginning of period		(85)			(85)			(64)			(90)		Balance, beginning of period		(32)			(62)			(31)			(64)
Other comprehensive income (loss)			2			5			(19)			10
Other comprehensive loss														Other comprehensive loss		—			(23)			(1)			(21)
Balance, end of period	Balance, end of period		(83)			(80)			(83)			(80)		Balance, end of period		(32)			(85)			(32)			(85)
Total Shareholders’ Equity	Total Shareholders’ Equity		$	9,989		$	8,865		$	9,989		$	8,865	Total Shareholders’ Equity		$	10,366		$	10,023		$	10,366		$	10,023

See Combined Notes to Interim Condensed Financial Statements

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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Revenues	Revenues	$	935	$	874	$	2,562	$	2,344	Revenues	$	909	$	881	$	1,701	$	1,627
Expenses:	Expenses:									Expenses:
Operation and maintenance	Operation and maintenance	395		396		1,193		1,159		Operation and maintenance	401		403		781		798
Depreciation and amortization	Depreciation and amortization	175		182		511		484		Depreciation and amortization	186		174		345		336
Taxes other than income taxes	Taxes other than income taxes	65		64		196		192		Taxes other than income taxes	67		68		131		131
Total	Total	635		642		1,900		1,835		Total	654		645		1,257		1,265
Operating Income	Operating Income	300		232		662		509		Operating Income	255		236		444		362
Other Income (Expense):	Other Income (Expense):									Other Income (Expense):
Interest expense and other finance charges	Interest expense and other finance charges	(50)		(46)		(148)		(138)		Interest expense and other finance charges	(63)		(50)		(116)		(98)
Interest expense on Securitization Bonds	Interest expense on Securitization Bonds	(3)		(5)		(11)		(16)		Interest expense on Securitization Bonds	(2)		(4)		(4)		(8)

Other income, net	Other income, net	5		4		13		12		Other income, net	10		4		17		8
Total	Total	(48)		(47)		(146)		(142)		Total	(55)		(50)		(103)		(98)
Income Before Income Taxes	Income Before Income Taxes	252		185		516		367		Income Before Income Taxes	200		186		341		264
Income tax expense	Income tax expense	52		34		108		60		Income tax expense	42		39		75		56
Net Income	Net Income	$	200	$	151	$	408	$	307	Net Income	$	158	$	147	$	266	$	208

See Combined Notes to Interim Condensed Financial Statements

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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Net income	Net income	$	200	$	151	$	408	$	307	Net income	$	158	$	147	$	266	$	208

Comprehensive income	Comprehensive income	$	200	$	151	$	408	$	307	Comprehensive income	$	158	$	147	$	266	$	208

See Combined Notes to Interim Condensed Financial Statements

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			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
ASSETS	ASSETS					ASSETS
Current Assets:	Current 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
Cash and cash equivalents ($62 and $75 related to VIEs, respectively)						Cash and cash equivalents ($62 and $75 related to VIEs, respectively)	$	62	$	75
Accounts receivable ($25 and $22 related to VIEs, respectively), less allowance for credit losses of $1 and $1, respectively						Accounts receivable ($25 and $22 related to VIEs, respectively), less allowance for credit losses of $1 and $1, respectively	333		311
Accounts and notes receivable–affiliated companies	Accounts and notes receivable–affiliated companies	389		11		Accounts and notes receivable–affiliated companies	14		21
Accrued unbilled revenues	Accrued unbilled revenues	147		127		Accrued unbilled revenues	136		142
Materials and supplies	Materials and supplies	408		292		Materials and supplies	479		471

Prepaid expenses and other current assets ($12 and $19 related to VIEs, respectively)		31		49
Prepaid expenses and other current assets ($12 and $13 related to VIEs, respectively)						Prepaid expenses and other current assets ($12 and $13 related to VIEs, respectively)	37		41
Total current assets	Total current assets	1,492		956		Total current assets	1,061		1,061
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Property, plant and equipment	Property, plant and equipment	16,988		15,273		Property, plant and equipment	18,658		17,753
Less: accumulated depreciation and amortization	Less: accumulated depreciation and amortization	4,295		4,070		Less: accumulated depreciation and amortization	4,383		4,292
Property, plant and equipment, net	Property, plant and equipment, net	12,693		11,203		Property, plant and equipment, net	14,275		13,461
Other Assets:	Other Assets:					Other Assets:
Regulatory assets ($265 and $420 related to VIEs, respectively)		768		789
Regulatory assets ($160 and $229 related to VIEs, respectively)						Regulatory assets ($160 and $229 related to VIEs, respectively)	828		778

Other non-current assets	Other non-current assets	38		32		Other non-current assets	50		39
Total other assets	Total other assets	806		821		Total other assets	878		817
Total Assets	Total Assets	$	14,991	$	12,980	Total Assets	$	16,214	$	15,339

See Combined Notes to Interim Condensed Financial Statements

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			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
LIABILITIES AND MEMBER’S EQUITY	LIABILITIES AND MEMBER’S EQUITY					LIABILITIES AND MEMBER’S EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:

Current portion of VIE Securitization Bonds long-term debt	Current portion of VIE Securitization Bonds long-term debt	$	153	$	220	Current portion of VIE Securitization Bonds long-term debt	$	159	$	156
Current portion of other long-term debt		200		300

Accounts payable	Accounts payable	438		510		Accounts payable	391		413
Accounts and notes payable–affiliated companies	Accounts and notes payable–affiliated companies	39		568		Accounts and notes payable–affiliated companies	192		755
Taxes accrued	Taxes accrued	159		193		Taxes accrued	115		150
Interest accrued	Interest accrued	57		74		Interest accrued	101		83

Other current liabilities	Other current liabilities	73		91		Other current liabilities	87		88
Total current liabilities	Total current liabilities	1,119		1,956		Total current liabilities	1,045		1,645
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes, net	Deferred income taxes, net	1,186		1,122		Deferred income taxes, net	1,290		1,229
Benefit obligations	Benefit obligations	53		55		Benefit obligations	38		38
Regulatory liabilities	Regulatory liabilities	1,186		1,152		Regulatory liabilities	953		1,155

Other non-current liabilities	Other non-current liabilities	101		98		Other non-current liabilities	125		77
Total other liabilities	Total other liabilities	2,526		2,427		Total other liabilities	2,406		2,499
Long-term Debt:	Long-term Debt:					Long-term Debt:
VIE Securitization Bonds, net	VIE Securitization Bonds, net	240		317		VIE Securitization Bonds, net	81		161
Other long-term debt, net	Other long-term debt, net	6,035		4,658		Other long-term debt, net	6,928		6,036
Total long-term debt, net	Total long-term debt, net	6,275		4,975		Total long-term debt, net	7,009		6,197
Commitments and Contingencies (Note 13)	Commitments and Contingencies (Note 13)					Commitments and Contingencies (Note 13)
Member’s Equity:	Member’s Equity:					Member’s Equity:
Common stock	Common stock	—		—		Common stock	—		—
Additional paid-in capital	Additional paid-in capital	3,860		2,678		Additional paid-in capital	4,510		3,860
Retained earnings	Retained earnings	1,211		944		Retained earnings	1,244		1,138

Total member’s equity	Total member’s equity	5,071		3,622		Total member’s equity	5,754		4,998
Total Liabilities and Member’s Equity	Total Liabilities and Member’s Equity	$	14,991	$	12,980	Total Liabilities and Member’s Equity	$	16,214	$	15,339

See Combined Notes to Interim Condensed Financial Statements

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,					Six Months Ended June 30,
		2022		2021			2023		2022
		(in millions)					(in millions)
Cash Flows from Operating Activities:	Cash Flows from Operating Activities:					Cash Flows from Operating Activities:
Net income	Net income	$	408	$	307	Net income	$	266	$	208
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	511		484		Depreciation and amortization	345		336
Deferred income taxes	Deferred income taxes	44		8		Deferred income taxes	53		36

Changes in other assets and liabilities:	Changes in other assets and liabilities:					Changes in other assets and liabilities:
Accounts and notes receivable, net	Accounts and notes receivable, net	(159)		(140)		Accounts and notes receivable, net	(16)		(119)
Accounts receivable/payable–affiliated companies	Accounts receivable/payable–affiliated companies	(35)		(31)		Accounts receivable/payable–affiliated companies	(24)		(24)
Inventory	Inventory	(116)		(49)		Inventory	(8)		(45)
Accounts payable	Accounts payable	(11)		60		Accounts payable	(18)		(7)

Net regulatory assets and liabilities	Net regulatory assets and liabilities	(40)		(190)		Net regulatory assets and liabilities	(192)		(112)
Other current assets and liabilities	Other current assets and liabilities	(43)		41		Other current assets and liabilities	(21)		(83)
Other non-current assets and liabilities	Other non-current assets and liabilities	(5)		13		Other non-current assets and liabilities	39		2
Other operating activities, net	Other operating activities, net	(9)		(6)		Other operating activities, net	(9)		(4)
Net cash provided by operating activities	Net cash provided by operating activities	545		497		Net cash provided by operating activities	415		188
Cash Flows from Investing Activities:	Cash Flows from Investing Activities:					Cash Flows from Investing Activities:
Capital expenditures	Capital expenditures	(1,727)		(1,108)		Capital expenditures	(1,185)		(1,140)
Increase in notes receivable–affiliated companies	Increase in notes receivable–affiliated companies	(360)		—		Increase in notes receivable–affiliated companies	—		(272)

Other investing activities, net	Other investing activities, net	34		4		Other investing activities, net	(13)		21
Net cash used in investing activities	Net cash used in investing activities	(2,053)		(1,104)		Net cash used in investing activities	(1,198)		(1,391)
Cash Flows from Financing Activities:	Cash Flows from Financing Activities:					Cash Flows from Financing Activities:

Proceeds from long-term debt	Proceeds from long-term debt	1,589		1,096		Proceeds from long-term debt	898		792
Payments of long-term debt	Payments of long-term debt	(444)		(540)		Payments of long-term debt	(77)		(112)
Increase (decrease) in notes payable–affiliated companies		(512)		32
Decrease in notes payable–affiliated companies						Decrease in notes payable–affiliated companies	(532)		(512)
Dividend to parent	Dividend to parent	(141)		—		Dividend to parent	(160)		(67)
Contribution from parent	Contribution from parent	1,143		—		Contribution from parent	650		1,143

Payment of debt issuance costs	Payment of debt issuance costs	(15)		(12)		Payment of debt issuance costs	(9)		(8)
Payment of obligation for finance lease	Payment of obligation for finance lease	(218)		—		Payment of obligation for finance lease	—		(171)

Other financing activities, net						Other financing activities, net	(1)		1
Net cash provided by financing activities	Net cash provided by financing activities	1,402		576		Net cash provided by financing activities	769		1,066
Net Decrease in Cash, Cash Equivalents and Restricted Cash	Net Decrease in Cash, Cash Equivalents and Restricted Cash	(106)		(31)		Net Decrease in Cash, Cash Equivalents and Restricted Cash	(14)		(137)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	Cash, Cash Equivalents and Restricted Cash at Beginning of Period	233		154		Cash, Cash Equivalents and Restricted Cash at Beginning of Period	88		233
Cash, Cash Equivalents and Restricted Cash at End of Period	Cash, Cash Equivalents and Restricted Cash at End of Period	$	127	$	123	Cash, Cash Equivalents and Restricted Cash at End of Period	$	74	$	96

See Combined Notes to Interim Condensed Financial Statements

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,							Three Months Ended June 30,						Six Months Ended June 30,
		2022			2021			2022			2021				2023			2022			2023			2022
		Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount			Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
		(in millions, except share amounts)													(in millions, except share amounts)

Common Stock	Common Stock													Common Stock
Balance, beginning of period	Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—	Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—
Balance, end of period	Balance, end 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	Additional Paid-in-Capital													Additional Paid-in-Capital
Balance, beginning of period	Balance, beginning of period		3,860			2,548			2,678			2,548		Balance, beginning of period		4,510			3,354			3,860			2,678
Non-cash contribution from parent	Non-cash contribution from parent		—			—			38			—		Non-cash contribution from parent		—			—			—			38
Contribution from parent	Contribution from parent		—			—			1,143			—		Contribution from parent		—			506			650			1,143
Other	Other		—			—			1			—		Other		—			—			—			1
Balance, end of period	Balance, end of period		3,860			2,548			3,860			2,548		Balance, end of period		4,510			3,860			4,510			3,860
Retained Earnings	Retained Earnings													Retained Earnings
Balance, beginning of period	Balance, beginning of period		1,085			719			944			563		Balance, beginning of period		1,195			968			1,138			944
Net income	Net income		200			151			408			307		Net income		158			147			266			208
Dividend to parent	Dividend to parent		(74)			—			(141)			—		Dividend to parent		(109)			(30)			(160)			(67)
Balance, end of period	Balance, end of period		1,211			870			1,211			870		Balance, end of period		1,244			1,085			1,244			1,085
Accumulated Other Comprehensive Loss
Balance, beginning of period			—			—			—			—

Balance, end of period			—			—			—			—

Total Member’s Equity	Total Member’s Equity		$	5,071		$	3,418		$	5,071		$	3,418	Total Member’s Equity		$	5,754		$	4,945		$	5,754		$	4,945

See Combined Notes to Interim Condensed Financial Statements

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					Three Months Ended				Six Months Ended
		September 30,				September 30,					June 30,				June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Revenues:	Revenues:									Revenues:
Utility revenues	Utility revenues	$	663	$	594	$	3,206	$	2,876	Utility revenues	$	733	$	788	$	2,440	$	2,543
Non-utility revenues	Non-utility revenues	9		15		26		49		Non-utility revenues	12		8		22		17
Total	Total	672		609		3,232		2,925		Total	745		796		2,462		2,560
Expenses:	Expenses:									Expenses:
Utility natural gas	Utility natural gas	276		173		1,660		1,230		Utility natural gas	260		351		1,258		1,384
Non-utility cost of revenues, including natural gas	Non-utility cost of revenues, including natural gas	1		4		3		16		Non-utility cost of revenues, including natural gas	—		1		1		2
Operation and maintenance	Operation and maintenance	190		223		630		709		Operation and maintenance	211		202		429		440
Depreciation and amortization	Depreciation and amortization	113		124		333		360		Depreciation and amortization	122		113		240		220
Taxes other than income taxes	Taxes other than income taxes	50		53		185		182		Taxes other than income taxes	59		60		128		135

Total	Total	630		577		2,811		2,497		Total	652		727		2,056		2,181
Operating Income	Operating Income	42		32		421		428		Operating Income	93		69		406		379
Other Income (Expense):	Other Income (Expense):									Other Income (Expense):
Gain on sale	Gain on sale	—		11		557		11		Gain on sale	—		—		—		557
Interest expense and other finance charges	Interest expense and other finance charges	(32)		(32)		(91)		(96)		Interest expense and other finance charges	(45)		(30)		(87)		(59)

Other expense, net		—		(2)		(11)		—

Other income (expense), net										Other income (expense), net	5		(11)		6		(11)
Total	Total	(32)		(23)		455		(85)		Total	(40)		(41)		(81)		487
Income Before Income Taxes	Income Before Income Taxes	10		9		876		343		Income Before Income Taxes	53		28		325		866
Income tax expense	Income tax expense	17		1		220		40		Income tax expense	10		1		70		203

Net Income (Loss)		$	(7)	$	8	$	656	$	303
Net Income										Net Income	$	43	$	27	$	255	$	663

See Combined Notes to Interim Condensed Financial Statements

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


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(in millions)
Net income	$	43	$	27	$	255	$	663

Adjustment to pension and other postretirement plans (net of tax of $-0-, $-0- ,$-0- and $-0-)	—		—		(1)		—

Other comprehensive loss	—		—		(1)		—
Comprehensive income	$	43	$	27	$	254	$	663

See Combined Notes to Interim Condensed Financial Statements

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			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	1	$	15	Cash and cash equivalents	$	1	$	—
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
Accounts receivable, less allowance for credit losses of $37 and $34, respectively						Accounts receivable, less allowance for credit losses of $37 and $34, respectively	257		463
Accrued unbilled revenues, less allowance for credit losses of $1 and $4, respectively						Accrued unbilled revenues, less allowance for credit losses of $1 and $4, respectively	117		573
Accounts receivable–affiliated companies						Accounts receivable–affiliated companies	19		52
Notes receivable–affiliated companies						Notes receivable–affiliated companies	417		—
Materials and supplies	Materials and supplies	104		82		Materials and supplies	101		98
Natural gas inventory	Natural gas inventory	267		151		Natural gas inventory	29		195
Non-trading derivative assets	Non-trading derivative assets	23		8		Non-trading derivative assets	1		7
Taxes receivable	Taxes receivable	21		28		Taxes receivable	—		12

Current assets held for sale		—		2,084

Regulatory assets	Regulatory assets	1,340		1,371		Regulatory assets	211		1,336
Prepaid expenses and other current assets	Prepaid expenses and other current assets	69		48		Prepaid expenses and other current assets	41		78
Total current assets	Total current assets	2,236		4,486		Total current assets	1,194		2,814
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Property, plant and equipment	Property, plant and equipment	14,075		12,934		Property, plant and equipment	15,102		14,379
Less: accumulated depreciation and amortization	Less: accumulated depreciation and amortization	3,985		3,826		Less: accumulated depreciation and amortization	4,092		3,973
Property, plant and equipment, net	Property, plant and equipment, net	10,090		9,108		Property, plant and equipment, net	11,010		10,406
Other Assets:	Other Assets:					Other Assets:
Goodwill	Goodwill	1,583		1,583		Goodwill	1,583		1,583
Regulatory assets	Regulatory assets	856		938		Regulatory assets	806		844
Non-trading derivative assets	Non-trading derivative assets	4		4		Non-trading derivative assets	—		2

Other non-current assets	Other non-current assets	31		34		Other non-current assets	53		55
Total other assets	Total other assets	2,474		2,559		Total other assets	2,442		2,484
Total Assets	Total Assets	$	14,800	$	16,153	Total Assets	$	14,646	$	15,704

See Combined Notes to Interim Condensed Financial Statements

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			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
LIABILITIES AND STOCKHOLDER’S EQUITY	LIABILITIES AND STOCKHOLDER’S EQUITY					LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:
Short-term borrowings	Short-term borrowings	$	514	$	7	Short-term borrowings	$	2	$	511
Current portion of long-term debt	Current portion of long-term debt	1,274		—		Current portion of long-term debt	57		1,331
Accounts payable	Accounts payable	389		503		Accounts payable	312		690
Accounts payable–affiliated companies	Accounts payable–affiliated companies	68		125		Accounts payable–affiliated companies	133		190
Notes payable–affiliated companies		—		441

Taxes accrued	Taxes accrued	112		152		Taxes accrued	87		140
Interest accrued	Interest accrued	41		30		Interest accrued	71		50
Customer deposits	Customer deposits	93		92		Customer deposits	94		94

Current liabilities held for sale		—		562

Other current liabilities	Other current liabilities	150		151		Other current liabilities	181		200
Total current liabilities	Total current liabilities	2,641		2,063		Total current liabilities	937		3,206
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes, net	Deferred income taxes, net	1,262		1,019		Deferred income taxes, net	1,302		1,262

Benefit obligations	Benefit obligations	96		100		Benefit obligations	76		76
Regulatory liabilities	Regulatory liabilities	1,815		1,715		Regulatory liabilities	1,828		1,801

Other non–current liabilities	Other non–current liabilities	565		571		Other non–current liabilities	512		501
Total other liabilities	Total other liabilities	3,738		3,405		Total other liabilities	3,718		3,640
Long-Term Debt	Long-Term Debt	3,297		5,552		Long-Term Debt	4,185		3,495
Commitments and Contingencies (Note 13)	Commitments and Contingencies (Note 13)					Commitments and Contingencies (Note 13)
Stockholder’s Equity:	Stockholder’s Equity:					Stockholder’s Equity:

Common stock						Common stock	—		—
Additional paid-in capital	Additional paid-in capital	3,565		4,106		Additional paid-in capital	4,229		3,729
Retained earnings	Retained earnings	1,549		1,017		Retained earnings	1,562		1,618
Accumulated other comprehensive income	Accumulated other comprehensive income	10		10		Accumulated other comprehensive income	15		16
Total stockholder’s equity	Total stockholder’s equity	5,124		5,133		Total stockholder’s equity	5,806		5,363
Total Liabilities and Stockholder’s Equity	Total Liabilities and Stockholder’s Equity	$	14,800	$	16,153	Total Liabilities and Stockholder’s Equity	$	14,646	$	15,704

See Combined Notes to Interim Condensed Financial Statements

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,					Six Months Ended June 30,
		2022		2021			2023		2022
		(in millions)					(in millions)
Cash Flows from Operating Activities:	Cash Flows from Operating Activities:					Cash Flows from Operating Activities:
Net income	Net income	$	656	$	303	Net income	$	255	$	663
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	333		360		Depreciation and amortization	240		220

Deferred income taxes	Deferred income taxes	217		41		Deferred income taxes	22		201

Gain on divestitures	Gain on divestitures	(557)		(11)		Gain on divestitures	—		(557)
Changes in other assets and liabilities:	Changes in other assets and liabilities:					Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	Accounts receivable and unbilled revenues, net	271		374		Accounts receivable and unbilled revenues, net	644		203
Accounts receivable/payable–affiliated companies	Accounts receivable/payable–affiliated companies	(59)		(4)		Accounts receivable/payable–affiliated companies	(24)		(40)
Inventory	Inventory	(87)		(77)		Inventory	168		60
Taxes receivable		—		(4)

Accounts payable	Accounts payable	(117)		(98)		Accounts payable	(372)		(110)

Net regulatory assets and liabilities	Net regulatory assets and liabilities	181		(2,153)		Net regulatory assets and liabilities	1,198		136

Other current assets and liabilities	Other current assets and liabilities	(81)		(57)		Other current assets and liabilities	10		(7)
Other non-current assets and liabilities	Other non-current assets and liabilities	(5)		(42)		Other non-current assets and liabilities	7		(3)
Other operating activities, net	Other operating activities, net	1		9		Other operating activities, net	(1)		1
Net cash provided by (used in) operating activities		753		(1,359)
Net cash provided by operating activities						Net cash provided by operating activities	2,147		767
Cash Flows from Investing Activities:	Cash Flows from Investing Activities:					Cash Flows from Investing Activities:
Capital expenditures	Capital expenditures	(1,166)		(805)		Capital expenditures	(807)		(688)
Increase in notes receivable–affiliated companies	Increase in notes receivable–affiliated companies	—		(25)		Increase in notes receivable–affiliated companies	(417)		—

Proceeds from divestiture	Proceeds from divestiture	2,075		22		Proceeds from divestiture	—		2,075
Other investing activities, net	Other investing activities, net	12		(39)		Other investing activities, net	(9)		7

Net cash provided by (used in) investing activities	Net cash provided by (used in) investing activities	921		(847)		Net cash provided by (used in) investing activities	(1,233)		1,394
Cash Flows from Financing Activities:	Cash Flows from Financing Activities:					Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net		457		(27)
Decrease in short-term borrowings, net						Decrease in short-term borrowings, net	(14)		(43)

Proceeds from (payments of) commercial paper, net		(324)		338
Proceeds from long-term debt		852		1,699
Payments of long-term debt		(425)		—
Payments of commercial paper, net						Payments of commercial paper, net	(805)		(325)
Proceeds from long-term debt and term loan						Proceeds from long-term debt and term loan	2,006		852
Payments of long-term debt and term loan						Payments of long-term debt and term loan	(2,275)		(425)

Dividends to parent	Dividends to parent	(844)		—		Dividends to parent	(311)		(831)
Payment of debt issuance costs	Payment of debt issuance costs	(11)		(10)		Payment of debt issuance costs	(13)		(8)
Increase (decrease) in notes payable–affiliated companies		(1,517)		203

Decrease in notes payable–affiliated companies						Decrease in notes payable–affiliated companies	—		(1,517)
Contribution from parent	Contribution from parent	125		—		Contribution from parent	500		125

Other financing activities, net	Other financing activities, net	(1)		(2)		Other financing activities, net	(1)		(1)

Net cash provided by (used in) financing activities		(1,688)		2,201
Net Decrease in Cash, Cash Equivalents and Restricted Cash		(14)		(5)
Net cash used in financing activities						Net cash used in financing activities	(913)		(2,173)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash						Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	1		(12)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	Cash, Cash Equivalents and Restricted Cash at Beginning of Period	15		6		Cash, Cash Equivalents and Restricted Cash at Beginning of Period	—		15
Cash, Cash Equivalents and Restricted Cash at End of Period	Cash, Cash Equivalents and Restricted Cash at End of Period	$	1	$	1	Cash, Cash Equivalents and Restricted Cash at End of Period	$	1	$	3

See Combined Notes to Interim Condensed Financial Statements

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,							Three Months Ended June 30,						Six Months Ended June 30,
		2022			2021			2022			2021				2023			2022			2023			2022
		Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount			Shares	Amount		Shares	Amount		Shares	Amount		Shares	Amount
		(in millions, except share amounts)													(in millions, except share amounts)
Common Stock	Common Stock													Common Stock
Balance, beginning of period	Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—	Balance, beginning of period	1,000	$	—	1,000	$	—	1,000	$	—	1,000	$	—
Balance, end of period	Balance, end 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	Additional Paid-in-Capital													Additional Paid-in-Capital
Balance, beginning of period	Balance, beginning of period		3,565			3,965			4,106			3,966		Balance, beginning of period		3,729			3,440			3,729			4,106
Non-cash contribution from parent	Non-cash contribution from parent		—			—			54			—		Non-cash contribution from parent		—			—			—			54
Contribution from parent	Contribution from parent		—			—			125			—		Contribution from parent		500			125			500			125
Contribution to parent for sale of Arkansas and Oklahoma Natural Gas businesses	Contribution to parent for sale of Arkansas and Oklahoma Natural Gas businesses		—			—			(720)			—		Contribution to parent for sale of Arkansas and Oklahoma Natural Gas businesses		—			—			—			(720)
Other			—			—			—			(1)

Balance, end of period	Balance, end of period		3,565			3,965			3,565			3,965		Balance, end of period		4,229			3,565			4,229			3,565
Retained Earnings	Retained Earnings													Retained Earnings
Balance, beginning of period	Balance, beginning of period		1,569			939			1,017			644		Balance, beginning of period		1,626			1,614			1,618			1,017
Net income	Net income		(7)			8			656			303		Net income		43			27			255			663
Dividend to parent	Dividend to parent		(13)			—			(124)			—		Dividend to parent		(107)			(72)			(311)			(111)
Balance, end of period	Balance, end of period		1,549			947			1,549			947		Balance, end of period		1,562			1,569			1,562			1,569
Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Income													Accumulated Other Comprehensive Income
Balance, beginning of period	Balance, beginning of period		10			10			10			10		Balance, beginning of period		15			10			16			10

Other comprehensive loss														Other comprehensive loss		—			—			(1)			—
Balance, end of period	Balance, end of period		10			10			10			10		Balance, end of period		15			10			15			10
Total Stockholder’s Equity	Total Stockholder’s Equity		$	5,124		$	4,922		$	5,124		$	4,922	Total Stockholder’s Equity		$	5,806		$	5,144		$	5,806		$	5,144

See Combined Notes to Interim Condensed Financial Statements

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~~2022 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. On June 30, 2023, CenterPoint Energy completed the sale of its indirect subsidiary, Energy Systems Group, to an unaffiliated third party. For additional information, see Note 3. 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~~June 30, ~~2022,~~2023, 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.~~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.~~CEIP; and

•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~~market.

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

As of ~~September~~June 30, ~~2022,~~2023, CenterPoint Energy’s reportable segments were Electric, Natural Gas and ~~Natural Gas.~~Corporate and Other. 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~~June 30, ~~2022,~~2023, 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. Additionally, CenterPoint Energy, through SIGECO, has a consolidated VIE consisting of the Securitization Subsidiary, a wholly-owned, bankruptcy-remote, special purpose entity that facilitated the securitization financing of qualified costs in the second quarter of 2023 associated with the planned retirement of SIGECO’s A.B. Brown coal generation facilities. CenterPoint Energy, through SIGECO, has a controlling financial interest in the Securitization Subsidiary and is the VIE’s primary beneficiary. For further information, see Note 6. Creditors of CenterPoint Energy, ~~and~~ Houston Electric and SIGECO have no recourse to any assets or revenues of the Bond ~~Companies.~~Companies or the Securitization Subsidiary, as applicable. The bonds issued by these VIEs are payable only from and secured

by transition, ~~and~~ system restoration or securitization property, as applicable, and the bondholders have no recourse to the general credit of CenterPoint Energy, Houston Electric or ~~Houston Electric.~~SIGECO.

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 Energy Systems Group. On May 21, 2023, CenterPoint Energy, through its subsidiary Vectren Energy Services, entered into an Equity Purchase Agreement to sell all of the outstanding limited liability company interests of Energy Systems Group to ESG Holdings Group, for a purchase price of $157 million, subject to customary adjustments set forth in the Equity Purchase Agreement, including adjustments based on Energy Systems Group’s net working capital at closing, indebtedness, cash and cash equivalents and transaction expenses. The transaction closed on June 30, 2023, and CenterPoint Energy received $154 million in cash, subject to finalization of the purchase price adjustment. Additionally, as of June 30, 2023, CenterPoint Energy had a payable to ESG Holdings Group for working capital and other adjustments set forth in the Equity Purchase Agreement.

During the three months ended June 30, 2023, certain assets and liabilities of Energy Systems Group met the held for sale criteria. The divestiture of Energy Systems Group reflects CenterPoint Energy’s continued strategic focus on its core utility businesses. The historical annual revenues, net income and total assets of Energy Systems Groups did not have a sufficient effect, quantitatively or qualitatively, on CenterPoint Energy’s financial results to be considered a strategic shift. Therefore, the income and expenses associated with Energy Systems Group were not reflected as discontinued operations on CenterPoint Energy’s Condensed Statements of Consolidated Income. For disposal groups that are classified as held for sale but that do not meet the criteria for discontinued operations reporting, the assets and liabilities of the disposal group are required to be separately presented on the face of the balance sheet only in the initial period in which it is classified as held for sale. Therefore, CenterPoint Energy’s Condensed Consolidated Balance Sheet as of December 31, 2022 was not recast to reflect Energy Systems Group’s assets and liabilities as held for sale. Depreciation and amortization of long-lived assets ceases at the end of the quarter in which the held for sale criteria is met. Additionally, as a result of the completion of the sale of Energy Systems Group in June 2023, there were no assets or liabilities classified as held for sale as of June 30, 2023. For a discussion of guarantees and product warranties related to Energy Systems Group prior to the sale, see Note 13(b).

CenterPoint Energy recognized a loss on sale of approximately $12 million, including $3 million of transaction costs, during the three and six months ended June 30, 2023, in connection with the closing of the sale of Energy Systems Group. Additionally, CenterPoint Energy recognized a current tax expense of $33 million during the three and six months ended June 30, 2023, as a result of the cash taxes payable upon the closing of the sale.

The pre-tax income (loss) for Energy Systems Group, excluding interest and corporate allocations, included in CenterPoint Energy’s Condensed Statements of Consolidated Income is as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(in millions)
Income (Loss) from Continuing Operations Before Income Taxes	$	2	$	2	$	(4)	$	(4)

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~~included 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.

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~~year ended ~~September 30,~~December 31, 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


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022 (1)
	(in millions)
Income from Continuing Operations Before Income Taxes	$	—	$	9

(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~~November 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.~~were terminated, and on January 10, 2023, all remaining services were terminated.

CenterPoint Energy’s charges to Southern Col Midco for reimbursement of transition services were ~~$10 million~~$-0- and ~~$29~~less than $1 million during the three and ~~nine~~six months ended ~~September~~June 30, 2023 and were $10 million and $19 million during the three and six months ended June 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 $7$-0- as of June 30, 2023 and $1 million as of ~~September 30,~~December 31, 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~~

~~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~~

~~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									Three Months Ended June 30, 2023
		Electric		Natural Gas		Corporate and Other		Total			Electric		Natural Gas		Corporate and Other		Total
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	1,155	$	686	$	65	$	1,906	Revenue from contracts	$	1,040	$	759	$	73	$	1,872

Other (1)	Other (1)	(9)		6		—		(3)		Other (1)	(3)		5		1		3

Total revenues	Total revenues	$	1,146	$	692	$	65	$	1,903	Total revenues	$	1,037	$	764	$	74	$	1,875

		Nine Months Ended September 30, 2022									Six Months Ended June 30, 2023
		Electric		Natural Gas		Corporate and Other		Total			Electric		Natural Gas		Corporate and Other		Total
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	3,113	$	3,358	$	182	$	6,653	Revenue from contracts	$	1,998	$	2,511	$	124	$	4,633
Other (1)	Other (1)	(21)		(24)		2		(43)		Other (1)	(9)		28		2		21

Total revenues	Total revenues	$	3,092	$	3,334	$	184	$	6,610	Total revenues	$	1,989	$	2,539	$	126	$	4,654


		Three Months Ended September 30, 2021									Three Months Ended June 30, 2022
		Electric		Natural Gas		Corporate and Other		Total			Electric		Natural Gas		Corporate and Other		Total
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	1,056	$	611	$	73	$	1,740	Revenue from contracts	$	1,060	$	827	$	72	$	1,959
Other (1)	Other (1)	—		8		1		9		Other (1)	(7)		(9)		1		(15)

Total revenues	Total revenues	$	1,056	$	619	$	74	$	1,749	Total revenues	$	1,053	$	818	$	73	$	1,944

		Nine Months Ended September 30, 2021									Six Months Ended June 30, 2022
		Electric		Natural Gas		Corporate and Other		Total			Electric		Natural Gas		Corporate and Other		Total
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	2,822	$	2,984	$	190	$	5,996	Revenue from contracts	$	1,958	$	2,672	$	117	$	4,747
Other (1)	Other (1)	1		38		3		42		Other (1)	(12)		(30)		2		(40)

Total revenues	Total revenues	$	2,823	$	3,022	$	193	$	6,038	Total revenues	$	1,946	$	2,642	$	119	$	4,707

(1)Primarily consists of income from ARPs and leases. Total lease income was $1$2 million and $2$3 million for the three months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and $5$4 million and $6$4 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

Houston Electric


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	949	$	880	$	2,597	$	2,358	Revenue from contracts	$	918	$	892	$	1,721	$	1,648
Other (1)	Other (1)	(14)		(6)		(35)		(14)		Other (1)	(9)		(11)		(20)		(21)
Total revenues	Total revenues	$	935	$	874	$	2,562	$	2,344	Total revenues	$	909	$	881	$	1,701	$	1,627

(1)Primarily consists of income from ARPs and leases. Lease income was not significant for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021.~~2022.

CERC


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Revenue from contracts	Revenue from contracts	$	667	$	602	$	3,257	$	2,893	Revenue from contracts	$	737	$	805	$	2,437	$	2,590
Other (1)	Other (1)	5		7		(25)		32		Other (1)	8		(9)		25		(30)

Total revenues	Total revenues	$	672	$	609	$	3,232	$	2,925	Total revenues	$	745	$	796	$	2,462	$	2,560

(1)Primarily consists of income from ARPs and leases. Lease income was not significant for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021.~~2022.

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.

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’and 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 assets and contract liabilities primarily ~~relate~~related to Energy Systems Group contracts where revenue iswas recognized using the input ~~method.~~method prior to the sale of Energy Systems Group that was completed on June 30, 2023.

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,~~are as ~~of December 31, 2021 and September 30, 2022, respectively, are presented below.~~follows:

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


	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Assets			Contract Liabilities
	(in millions)
Opening balance as of December 31, 2022	$	858	$	764	$	4		$	45
Closing balance as of June 30, 2023	608		289		—			6
Decrease	$	(250)	$	(475)	$	(4)	(1)	$	(39)	(1)

(1)Decrease primarily related to the completed sale of Energy Systems Group on June 30, 2023.

The amount of revenue recognized during the ~~nine-month~~three-month period ended ~~September~~June 30, ~~2022~~2023 that was included in the opening contract liability was ~~$15~~$2 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 $ —


	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2022	$	271	$	142	$	2
Closing balance as of June 30, 2023	306		136		6
Increase (decrease)	$	35	$	(6)	$	4

The amount of revenue recognized during the ~~nine-month~~three-month period ended ~~September~~June 30, ~~2022~~2023 that was included in the opening contract liability was $3$1 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)


	Accounts Receivable		Other Accrued Unbilled Revenues
	(in millions)
Opening balance as of December 31, 2022	$	478	$	573
Closing balance as of June 30, 2023	267		117
Decrease	$	(211)	$	(456)

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

Remaining Performance Obligations (CenterPoint Energy). ~~The table below discloses (1)~~Following 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 contractscompleted sale of Energy Systems Group ~~which are included in Corporate and Other.~~on June 30, 2023, CenterPoint Energy had no remaining performance obligations.

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~~had no material changes in its methodology to recognize losses on financial assets that fall under the scope of Topic ~~326. Losses on financial assets are~~326, primarily ~~recoverable through~~due to the nature of its customers and regulatory ~~mechanisms and do not materially impact Houston Electric's allowance for credit losses.~~environment. For a discussion of regulatory deferrals, including those related to ~~the February 2021 Winter Storm Event,~~COVID-19, 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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Service cost (1)	Service cost (1)	$	7	$	9	$	23	$	29	Service cost (1)	$	6	$	8	$	13	$	16
Interest cost (2)	Interest cost (2)	20		15		52		44		Interest cost (2)	19		17		38		32
Expected return on plan assets (2)	Expected return on plan assets (2)	(21)		(26)		(69)		(78)		Expected return on plan assets (2)	(19)		(23)		(38)		(48)

Amortization of net loss (2)	Amortization of net loss (2)	8		9		22		28		Amortization of net loss (2)	7		7		14		14
Settlement cost (benefit) (2) (3)		8		27		38		26
Settlement cost (2) (3)										Settlement cost (2) (3)	—		30		—		30

Net periodic cost	Net periodic cost	$	22	$	34	$	66	$	49	Net periodic cost	$	13	$	39	$	27	$	44

(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.

Postretirement Benefits


		Three Months Ended September 30,													Three Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Service cost (1)	Service cost (1)	$	—	$	—	$	1	$	1	$	—	$	—	Service cost (1)	$	1	$	—	$	—	$	—	$	—	$	—
Interest cost (2)	Interest cost (2)	3		1		1		2		1		1		Interest cost (2)	3		2		1		2		1		1
Expected return on plan assets (2)	Expected return on plan assets (2)	(1)		(1)		(1)		(1)		(1)		—		Expected return on plan assets (2)	(2)		(1)		—		(1)		(1)		—
Amortization of prior service credit (2)	Amortization of prior service credit (2)	(1)		(1)		—		(1)		(1)		—		Amortization of prior service credit (2)	(1)		(2)		—		—		(1)		1
Amortization of net loss (2)	Amortization of net loss (2)	(1)		(1)		—		—		—		—		Amortization of net loss (2)	(2)		(1)		—		(1)		—		(1)

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

		Nine Months Ended September 30,													Six Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Service cost (1)	Service cost (1)	$	1	$	—	$	1	$	2	$	—	$	1	Service cost (1)	$	1	$	—	$	—	$	1	$	—	$	—
Interest cost (2)	Interest cost (2)	7		3		3		6		3		2		Interest cost (2)	6		3		2		4		2		2
Expected return on plan assets (2)	Expected return on plan assets (2)	(3)		(3)		(1)		(3)		(3)		—		Expected return on plan assets (2)	(3)		(2)		—		(2)		(2)		—
Amortization of prior service cost (credit) (2)	Amortization of prior service cost (credit) (2)	(2)		(3)		1		(3)		(3)		—		Amortization of prior service cost (credit) (2)	(1)		(3)		1		(1)		(2)		1
Amortization of net loss (2)	Amortization of net loss (2)	(3)		(2)		(1)		—		—		—		Amortization of net loss (2)	(4)		(2)		(1)		(2)		(1)		(1)

Net periodic cost (benefit)	Net periodic cost (benefit)	$	—	$	(5)	$	3	$	2	$	(3)	$	3	Net periodic cost (benefit)	$	(1)	$	(4)	$	2	$	—	$	(3)	$	2

(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:~~2023:

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


	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2023	$	7	$	—	$	—
Expected minimum contribution to postretirement benefit plans in 2023	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							Three Months Ended June 30, 2023						Six Months Ended June 30, 2023
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Pension plans	Pension plans	$	2	$	—	$	—	$	6	$	—	$	—	Pension plans	$	2	$	—	$	—	$	4	$	—	$	—
Postretirement benefit plans	Postretirement benefit plans	2		—		1		6		1		3		Postretirement benefit plans	2		—		1		4		—		2

(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


	June 30, 2023						December 31, 2022
	CenterPoint Energy (1)		Houston Electric (2)		CERC (3)		CenterPoint Energy (1)		Houston Electric (2)		CERC (3)
	(in millions)
Allowed equity return not recognized	$	210	$	91	$	63	$	188	$	82	$	54

(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~~including investments at SIGECO and securitized qualified costs associated with ~~investments at SIGECO.~~the planned retirements of Indiana Electric’s A.B. Brown coal-fired generation facilities.

(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, TEEEF and ~~TEEEF~~LLTF 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,													Three Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Allowed equity return recognized	Allowed equity return recognized	$	14	$	12	$	1	$	12	$	11	$	—	Allowed equity return recognized	$	10	$	9	$	—	$	12	$	12	$	1

		Nine Months Ended September 30,													Six Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Allowed equity return recognized	Allowed equity return recognized	$	36	$	33	$	2	$	31	$	29	$	1	Allowed equity return recognized	$	18	$	16	$	1	$	22	$	21	$	1

February 2021 Winter Storm Event

~~Amounts for~~In February 2021, certain of the ~~under recovery~~Registrants’ jurisdictions experienced an extreme and unprecedented winter weather event that resulted in prolonged freezing temperatures, which impacted their businesses. The February 2021 Winter Storm Event impacted wholesale prices of CenterPoint Energy’s and CERC’s natural gas ~~costs associated with~~purchases and their ability to serve customers in their Natural Gas service territories, including due to the reduction in available natural gas capacity and impacts to CenterPoint Energy’s and CERC’s natural gas supply portfolio activities, and the effects of weather on their systems and their ability to transport natural gas, among other things. The overall natural gas market, including the markets from which CenterPoint Energy and CERC sourced a significant portion of their natural gas for their operations, experienced significant impacts caused by the February 2021 Winter Storm Event, ~~are reflected~~resulting in ~~current and non-current regulatory assets on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets. Recovery~~extraordinary increases in the cost of natural gas ~~costs within the regulatory assets as~~purchased by CenterPoint Energy and CERC 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.~~approximately $2 billion. CenterPoint Energy and CERC have ~~begun~~completed recovery of natural gas costs in ~~Louisiana,~~ Mississippi, Indiana and ~~Minnesota,~~Texas discussed further below, and ~~recovery of~~continue to recover the natural gas ~~costs~~cost in ~~Indiana is complete.~~Louisiana and Minnesota. As of June 30, 2023, 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

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~~each recorded current regulatory assets of ~~$1,175~~$104 million and non-current regulatory assets of ~~$225~~$140 million associated with the February 2021 Winter Storm Event. As of December 31, ~~2021,~~2022, CenterPoint Energy and CERC have each recorded current regulatory assets of ~~$1,410~~$1,175 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~~$202 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.

In Minnesota, the MPUC issued its written order on October 19, 2022 disallowing CERC’s recovery of approximately $36 million of the $409 million incurred, and CERC’s regulatory asset balance was reduced to reflect the disallowance. CERC filed a petition for reconsideration on November 8, 2022 and a written order denying the petition for reconsideration was issued on January 6, 2023.

CenterPoint Energy and CERC have approximately $75 million of the total $2 billion of natural gas costs incurred during the February 2021 Winter Storm Event remaining under prudence review. Recovery of natural gas costs within the regulatory assets as of June 30, 2023 are probable and only natural gas costs in Louisiana are still subject to customary regulatory prudence reviews, which may impact the amount ultimately recovered in Louisiana.

As of both ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, as authorized by the PUCT, both 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~~$17 million and ~~$15~~$16 million as of ~~September~~both June 30, ~~2022~~2023 and December 31, ~~2021, respectively,~~2022, to defer operations and maintenance costs associated with the February 2021 Winter Storm Event.

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

Texas Public Securitization. The Texas Natural Gas Securitization Finance Corporation issued customer rate relief bonds in March 2023, and on March 23, 2023, CenterPoint Energy and CERC, collectively, received approximately $1.1 billion in cash proceeds from the state’s customer rate relief bonds. The proceeds from the state’s customer rate relief bonds included carrying costs incurred through August 2022. Incremental carrying costs incurred after August 2022 until the date the proceeds were received are recorded in a separate regulatory asset to be included for recovery in a subsequent rate proceeding. As CenterPoint

Energy and CERC have no future financial obligations for the repayment of the state’s customer rate relief bonds, the customer rate relief bonds are not recorded on CenterPoint Energy’s or CERC’s balance sheets. The $1.1 billion in cash proceeds from the customer rate relief bonds is considered to be a government grant. The state’s customer rate relief bonds are backed in part by customer rate relief property, including customer rate relief charges, which are non-bypassable uniform monthly volumetric charges to be paid by all existing and future customers as a component of each regulated utility’s gas cost or in another manner that the Railroad Commission determines reasonable, separate from their base rate. CERC only acts as a collection agent, whose duties include management, servicing and administration of a portion of the customer rate relief property which is associated with the customer rate relief charge imposed on customers of CERC under the guidance and direction from the Railroad Commission. The Texas Natural Gas Securitization Finance Corporation, and not CenterPoint Energy or CERC, is the owner of the customer rate relief property. The assets of the Texas Natural Gas Securitization Finance Corporation are not available to pay creditors of CenterPoint Energy, CERC, or their affiliates. While the customer rate relief charges will be included by CERC in their monthly billings, the billing amount is established by the Railroad Commission. CERC will remit all customer rate relief charges to the financing entity set up by the Railroad Commission. Therefore, the collection and servicing of customer rate relief charges have no impact on the respective Condensed Statements of Consolidated Income of CenterPoint Energy or CERC.

As U.S. generally accepted accounting principles have no specific accounting guidance for government grants or assistance, the cash proceeds from the state’s customer rate relief bonds were accounted for as a government grant by analogy to the grant model under IAS 20—Accounting for Government Grants and Disclosures of Government Assistance. CenterPoint Energy and CERC reflect the proceeds from the grant as a deduction to natural gas costs and recognized the $1.1 billion of cash proceeds from the state’s customer rate relief bonds within Utility natural gas expense on their respective Condensed Statements of Consolidated Income in the six months ended June 30, 2023, net of the recognition of natural gas cost related to relieving CenterPoint Energy and CERC’s regulatory assets related to the February 2021 Winter Storm Event in the same period.

Indiana Electric Securitization of Planned Generation Retirements (CenterPoint Energy)

On January 4, 2023, the IURC issued an order in accordance with Indiana Senate Enrolled Act 386 authorizing the issuance of up to $350 million in securitization bonds to securitize qualified costs associated with the planned retirements of Indiana Electric’sA.B. Brown coal-fired generation facilities. Accordingly, CenterPoint Energy determined that the retirement of property, plant and equipment became probable upon the issuance of the order. No loss on abandonment was recognized in connection with issuance of the order as there was no disallowance of all or part of the cost of the abandoned property, plant and equipment. In the first quarter of 2023, upon receipt of the order, CenterPoint Energy reclassified property, plant and equipment to be recovered through securitization to a regulatory asset and such amounts continued to earn a full return until recovered through securitization.

On March 24, 2023, SIGECO and the Securitization Subsidiary filed a registration statement on Form SF-1, amended on May 16, 2023, under the Securities Act of 1933, as amended, with the SEC registering the public offering and sale of approximately $341 million aggregate principal amount of the SIGECO Securitization Bonds. The registration statement became effective on June 12, 2023. The Securitization Subsidiary issued $341 million aggregate principal amount of the SIGECO Securitization Bonds on June 29, 2023. See Note 11 for further details of the issuance. The Securitization Subsidiary used the net proceeds from the issuance to purchase the securitization property from SIGECO. No gain or loss was recognized.

The SIGECO Securitization Bonds are secured by the securitization property, which includes the right to recover, through non-bypassable securitization charges payable by SIGECO’s retail electric customers, the qualified costs of SIGECO authorized by the IURC order. SIGECO has no payment obligations with respect to the SIGECO Securitization Bonds except to remit collections of securitization charges as set forth in a servicing agreement between SIGECO and the Securitization Subsidiary. The non-bypassable securitization charges are subject to a true-up mechanism.

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, seekinginitially sought recovery of deferred costs and the applicable return as of December 31, 2021 under these lease agreements of approximately $200 ~~million.~~million in its DCRF application filed with the PUCT on April 5, 2022, and subsequently amended on July 1, 2022, to show mobile generation in a separate Rider TEEEF. The annual revenue increase requested for these lease agreements iswas approximately $57 million. ~~Intervenors~~A final order was issued on April 5, 2023 approving a reduced revenue requirement of $39 million that results 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 disallowsfull recovery of ~~TEEEF~~ costs ~~and~~requested but lengthens 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.

short-

3028

term lease to be collected over 82.5 months. On April 28, 2023, and May 1, 2023, certain intervenors filed motions for rehearing of the PUCT’s April 5, 2023 order. On May 25, 2023, the PUCT issued its order on rehearing which clarified some of the findings, but did not change the approval of TEEEF cost recovery. On June 19, 2023, certain intervenors filed motions for rehearing of the PUCT’s May 25, 2023 Order on Rehearing; the PUCT voted to add the motions for rehearing to the August 3, 2023 open meeting agenda for consideration of the merits. The ultimate outcome of these proceedings cannot be predicted at this time.

On April 5, 2023, Houston Electric made its second TEEEF filing requesting recovery of TEEEF related costs incurred through December 31, 2022. Houston Electric is requesting a new annual revenue requirement of approximately $188 million using 78 months to amortize the related deferred costs for proposed rates beginning September 2023, a net increase in TEEEF revenues of approximately $149 million. On June 7, 2023, intervenors jointly requested a hearing, and on June 14, 2023, the PUCT staff indicated that it does not oppose a hearing in this docket. On June 21, 2023 Houston Electric made a filing that a hearing is not necessary given the PUCT’s decision in the TEEEF docket filed in 2022 and indicated that if the PUCT does refer this case to the State Office of Administrative Hearings, any preliminary order issued by the PUCT should be limited. On July 18, 2023 the PUCT referred the case to the State Office of Administrative Hearings and, on July 20, 2023, the PUCT issued a preliminary order identifying the issues to be addressed. The ultimate outcome of these proceedings cannot be predicted at this time.

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 debt returns, and determined that such regulatory assets remain probable of recovery as of ~~September~~June 30, ~~2022.~~2023. 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~~has not ~~record~~recorded any impairments on its right of use assets in the ~~three~~year ended December 31, 2022 or ~~nine~~the six months ended ~~September~~June 30, ~~2022.~~2023. See Note 19 for further information.

COVID-19 Regulatory Matters

Regulatory commissions in Indiana Electric’s and CenterPoint Energy’s and CERC’s Natural Gas service territories have either (1) issued orders to record a regulatory asset for incremental bad debt expenses related to COVID-19, including costs associated with the suspension of disconnections and payment plans, or (2) provided authority to recover bad debt expense through an existing tracking mechanism. CenterPoint Energy and CERC have recorded estimated incremental uncollectible receivables to the associated regulatory asset of $18 million and $17 million, respectively, as of both June 30, 2023 and December 31, 2022. CenterPoint Energy and CERC both have $7 million remaining to recover through rates and other sources as of June 30, 2023, and $11 million and $10 million, respectively, remaining to recover through rates and other sources as of December 31, 2022, respectively.

(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 they respectively own, 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. All other financial instruments do not qualify or are not designated as cash flow or fair value hedges.

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


	June 30, 2023		December 31, 2022
Hedging Classification	Notional Principal
	CenterPoint Energy		CenterPoint Energy
	(in millions)
Economic hedge (1)	$	—	$	84
Cash flow hedge (2)	75		—

(1)Relates to interest rate derivative instruments at ~~SIGECO. On June 13, 2022,~~ SIGECO ~~amended the LIBOR~~that terminated on May 1, 2023.

(2)Relates to an interest rate ~~swaps to adjust the~~derivative instrument at CenterPoint Energy with a termination date ~~to May 1,~~of August 29, 2023. The interest rate swap contract was designated as a cash flow hedge of a forecasted transaction. CenterPoint Energy records all changes in the fair value of cash flow hedges in accumulated other comprehensive income (loss) until the underlying hedged transaction occurs, when it reclassifies that amount into earnings. The effect of cash flow hedge accounting in accumulated other comprehensive income (loss) for the three and six months ended June 30, 2023, was immaterial.

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.

(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


		June 30, 2023				December 31, 2022
	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	$	1	$	—	$	9	$	—
Natural gas derivatives (1)	Other Assets: Non-trading derivative assets	—		—		2		—

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



Indexed debt securities derivative (2)	Current Liabilities	—		583		—		578

Total		$	1	$	583	$	12	$	578

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 $ —


		June 30, 2023				December 31, 2022
	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	$	1	$	—	$	7	$	—
Natural gas derivatives (1)	Other Assets: Non-trading derivative assets	—		—		2		—






Total		$	1	$	—	$	9	$	—

(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,						Three Months Ended June 30,				Six Months Ended June 30,
		Income Statement Location	2022		2021		2022		2021			Income Statement Location	2023		2022		2023		2022
Derivatives not designated as hedging instruments:	Derivatives not designated as hedging instruments:		(in millions)								Derivatives not designated as hedging instruments:		(in millions)
Indexed debt securities derivative (1)	Indexed debt securities derivative (1)	Gain (loss) on indexed debt securities	$	210	$	11	$	381	$	(40)	Indexed debt securities derivative (1)	Gain (loss) on indexed debt securities	$	34	$	65	$	(5)	$	171

(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

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~~June 30, 2023 and December 31, 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~~June 30, ~~2022~~2023 and December 31, ~~2021~~2022 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									June 30, 2023										December 31, 2022
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3				Total			Level 1		Level 2		Level 3			Total		Level 1		Level 2		Level 3		Total
Assets	Assets	(in millions)														Assets	(in millions)
Equity securities	Equity securities	$	452	$	—	$	—	$	452	$	1,439	$	—	$	—			$	1,439	Equity securities	$	517	$	—	$	—		$	517	$	510	$	—	$	—	$	510
Investments, including money market funds (1)	Investments, including money market funds (1)	32		—		—		32		42		—		—				42		Investments, including money market funds (1)	31		—		—			31		32		—		—		32
Interest rate derivatives	Interest rate derivatives	—		1		—		1		—		—		—				—		Interest rate derivatives	—		—		—			—		—		1		—		1
Natural gas derivatives	Natural gas derivatives	—		34		—		34		—		14		—				14		Natural gas derivatives	—		1		—			1		—		11		—		11

Total assets	Total assets	$	484	$	35	$	—	$	519	$	1,481	$	14	$	—			$	1,495	Total assets	$	548	$	1	$	—		$	549	$	542	$	12	$	—	$	554
Liabilities	Liabilities																			Liabilities
Indexed debt securities derivative	Indexed debt securities derivative	$	—	$	522	$	—	$	522	$	—	$	903	$	—			$	903	Indexed debt securities derivative	$	—	$	583	$	—		$	583	$	—	$	578	$	—	$	578
Interest rate derivatives		—		—		—		—		—		14		—				14

Total liabilities	Total liabilities	$	—	$	522	$	—	$	522	$	—	$	917	$	—			$	917	Total liabilities	$	—	$	583	$	—		$	583	$	—	$	578	$	—	$	578

Houston Electric


		September 30, 2022						December 31, 2021									June 30, 2023								December 31, 2022
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3				Total			Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets	Assets	(in millions)														Assets	(in millions)
Investments, including money market funds (1)	Investments, including money market funds (1)	$	17	$	—	$	—	$	17	$	27	$	—	$	—			$	27	Investments, including money market funds (1)	$	15	$	—	$	—	$	15	$	17	$	—	$	—	$	17

Total assets	Total assets	$	17	$	—	$	—	$	17	$	27	$	—	$	—			$	27	Total assets	$	15	$	—	$	—	$	15	$	17	$	—	$	—	$	17

CERC


		September 30, 2022						December 31, 2021									June 30, 2023										December 31, 2022
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3				Total			Level 1		Level 2		Level 3			Total		Level 1		Level 2		Level 3		Total
Assets	Assets	(in millions)														Assets	(in millions)

Investments, including money market funds (1)	Investments, including money market funds (1)	$	13	$	—	$	—	$	13	$	14	$	—	$	—			$	14	Investments, including money market funds (1)	$	14	$	—	$	—		$	14	$	14	$	—	$	—	$	14
Natural gas derivatives	Natural gas derivatives	—		27		—		27		—		12		—				12		Natural gas derivatives	—		1		—			1		—		9		—		9
Total assets	Total assets	$	13	$	27	$	—	$	40	$	14	$	12	$	—			$	26	Total assets	$	14	$	1	$	—		$	15	$	14	$	9	$	—	$	23

(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							June 30, 2023						December 31, 2022
		CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC			CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	Long-term debt, including current maturities	(in millions)												Long-term debt, including current maturities	(in millions)

Carrying amount	Carrying amount	$	15,066	$	6,628	$	4,571	$	16,086	$	5,495	$	5,552	Carrying amount	$	16,958	$	7,168	$	4,242	$	16,338	$	6,353	$	4,826
Fair value	Fair value	13,482		5,649		4,324		17,385		6,230		5,999		Fair value	15,694		6,340		4,086		14,990		5,504		4,637

(1)Includes Securitization ~~Bond debt.~~Bonds, as applicable.

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

Goodwill (CenterPoint Energy and CERC)

CenterPoint Energy’s goodwill by reportable segment is as follows:


	December 31, 2022		Disposals			June 30, 2023
	(in millions)
Electric (1)	$	936	$	—		$	936
Natural Gas	2,920		—			2,920
Corporate and Other	438		134		(2)	304

Total	$	4,294	$	134		$	4,160

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

(2)Represents goodwill attributable to the sale of Energy Systems Group. For further information, see Note 3.

CERC’s goodwill as of both ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021~~2022 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.~~

~~(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~~As described further in Note 3, certain assets 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 exceptionliabilities of Energy Systems Group, ~~which is a separate reporting unit but included~~including goodwill of $134 million at CenterPoint Energy, were disposed of upon consummation of the sale of Energy Systems Group in the ~~Corporate and Other reconciling category at CenterPoint Energy.~~second quarter of 2023. The ~~estimated fair value~~disposal 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, notgoodwill attributable to ~~exceed the carrying amount of goodwill.~~

~~CenterPoint~~ Energy ~~and CERC performed their annual goodwill impairment tests~~Systems Group was reflected in the ~~third quarter~~loss on sale of ~~2022~~$12 million during the three and ~~determined that no goodwill impairment charge was required for any reporting unit as a result of those tests.~~

six months ended June 30, 2023.

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. The intangible assets and associated amortization expense are primarily related to Energy Systems Group prior to the completion of the sale in June 2023 as indicated below. See Note 3 for further information.


		September 30, 2022						December 31, 2021							June 30, 2023						December 31, 2022
		Gross Carrying Amount		Accumulated Amortization		Net Balance		Gross Carrying Amount		Accumulated Amortization		Net Balance			Gross Carrying Amount		Accumulated Amortization		Net Balance		Gross Carrying Amount		Accumulated Amortization		Net Balance
		(in millions)													(in millions)
Customer relationships(1)	Customer relationships(1)	$	33	$	(15)	$	18	$	33	$	(12)	$	21	Customer relationships(1)	$	—	$	—	$	—	$	33	$	(16)	$	17

Trade names(1)	Trade names(1)	16		(6)		10		16		(5)		11		Trade names(1)	—		—		—		16		(6)		10

Operation and maintenance agreements (1)		12		(1)		11		12		(1)		11
Operation and maintenance agreements (1) (2)														Operation and maintenance agreements (1) (2)	—		—		—		12		(2)		10
Other	Other	2		(1)		1		2		(1)		1		Other	2		(1)		1		2		(1)		1
Total	Total	$	63	$	(23)	$	40	$	63	$	(19)	$	44	Total	$	2	$	(1)	$	1	$	63	$	(25)	$	38

(1)Related to Energy Systems Group prior to the completion of the sale in June 2023. Amortization ceased at June 30, 2023, the end of the quarter in which the held for sale criteria was met. See Note 3 for further information.

(2)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. Amortization ceased at June 30, 2023, the end of the quarter in which the held for sale criteria was met. See Note 3 for further information.

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

3533


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	2	$	2	$	3	$	3

CenterPoint Energy estimates that amortization expense of intangible assets with finite lives for the next five years will not be ~~as follows:~~

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

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

(a) Equity Securities

During ~~February and March~~the six months ended June 30, 2022, CenterPoint Energy ~~executed~~completed the execution of 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.~~held.

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									Gains (Losses) on Equity Securities
		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
AT&T Common	AT&T Common	$	(57)	$	(18)	$	(94)	$	(18)	AT&T Common	$	(34)	$	(27)	$	(25)	$	(37)
Charter Common	Charter Common	(144)		6		(304)		58		Charter Common	9		(67)		25		(160)
WBD Common	WBD Common	(5)		—		28		—		WBD Common	(6)		33		8		33
Energy Transfer Common Units	Energy Transfer Common Units	—		—		95		—		Energy Transfer Common Units	—		—		—		95
Energy Transfer Series G Preferred Units	Energy Transfer Series G Preferred Units	—		—		(9)		—		Energy Transfer Series G Preferred Units	—		—		—		(9)
Other	Other	—		—		—		—		Other	—		—		(1)		—
Total	Total	$	(206)	$	(12)	$	(284)	$	40	Total	$	(31)	$	(61)	$	7	$	(78)

CenterPoint Energy recorded net unrealized ~~losses~~gains (losses) of ~~$206~~$(31) million and ~~$370~~$7 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and net unrealized ~~loss~~losses of ~~$12~~$61 million and ~~net unrealized gain of $40~~$164 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021~~2022 respectively, for equity securities held as of ~~September~~June 30, ~~2022~~2023 and ~~2021.~~2022.

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					Shares Held		Carrying Value
		September 30, 2022	December 31, 2021	September 30, 2022		December 31, 2021			June 30, 2023	December 31, 2022	June 30, 2023		December 31, 2022
				(in millions)							(in millions)
AT&T Common	AT&T Common	10,212,945	10,212,945	$	157	$	251	AT&T Common	10,212,945	10,212,945	$	163	$	188
Charter Common	Charter Common	872,503	872,503	265		569		Charter Common	872,503	872,503	321		296
WBD Common	WBD Common	2,470,685	—	28		—		WBD Common	2,470,685	2,470,685	31		23
Energy Transfer Common Units		—	50,999,768	—		420
Energy Transfer Series G Preferred Units		—	192,390	—		196

Other	Other			2		3		Other			2		3
Total	Total			$	452	$	1,439	Total			$	517	$	510

(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~~June 30, ~~2022.~~2023. 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		June 30, 2023	December 31, 2022
		(in shares)			(in shares)
AT&T Common	AT&T Common	0.7185	0.7185	AT&T Common	0.7185	0.7185
Charter Common	Charter Common	0.061382	0.061382	Charter Common	0.061382	0.061382
WBD Common	WBD Common	0.173817	—	WBD Common	0.173817	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~~June 30, ~~2022,~~2023, the ZENS, having an original principal amount of $828 million and a contingent principal amount of ~~$29~~$22 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~~Certain of these transactions are accounted for as an inventory financing. CenterPoint Energy and CERC had ~~$14~~$2 million and $7$11 million outstanding obligations related to the AMAs as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, 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.

Debt Transactions. During the ~~nine~~six months ended ~~September~~June 30, ~~2022, in addition to CERC’s debt exchange discussed further below,~~2023, the following debt instruments were issued or incurred:


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

Houston Electric	Houston Electric	February 2022	General Mortgage Bonds (1)	$	300	3.00%	2032	Houston Electric	March 2023	General Mortgage Bonds (1)	$	600	4.95%	2033
Houston Electric	Houston Electric	February 2022	General Mortgage Bonds (1)	500		3.60%	2052	Houston Electric	March 2023	General Mortgage Bonds (1)	300		5.30%	2053
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						Total Houston Electric	900
CERC	CERC	June 2022	Senior Notes (3)	500		4.40%	2032	CERC	February 2023	Term Loan (2)	500		SOFR (3) + 0.85%	2024
CERC	CERC	August 2022	Term Loan (4)	500		SOFR (5) + 0.70%	2023	CERC	February 2023	Senior Notes (4)	600		5.25%	2028
CERC								CERC	February 2023	Senior Notes (4)	600		5.40%	2033
CERC								CERC	May 2023	Senior Notes (5)	300		5.25%	2028
			Total CERC	1,000						Total CERC	2,000
CenterPoint Energy (6)								CenterPoint Energy (6)	March 2023	First Mortgage Bonds (7)	100		4.98%	2028
CenterPoint Energy (6)								CenterPoint Energy (6)	March 2023	First Mortgage Bonds (7)	80		5.04%	2033
CenterPoint Energy								CenterPoint Energy	March 2023	Term Loan (8)	250		SOFR (3) + 1.50%	2023
CenterPoint Energy (9)								CenterPoint Energy (9)	June 2023	Securitization Bonds (10)	341		5.026% - 5.172%	2038-2043
			Total CenterPoint Energy	$	2,600					Total CenterPoint Energy	$	3,671

(1)Total proceeds from Houston Electric’s March 2023 issuances of general mortgage bonds, net of ~~discounts and issuance~~transaction expenses and fees, were approximately $890 million. Approximately $593 million of ~~approximately $784 million~~such proceeds 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~~working capital ~~expenditures,~~and the repayment of all or a portion of Houston Electric’s borrowings under the CenterPoint Energy money pool, and ~~the redemption~~approximately $296 million of ~~outstanding general mortgage bonds discussed below.~~such proceeds will be disbursed or allocated to finance or refinance, in part or in full, new or existing projects that meet stated criteria.

~~(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)~~(2)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)~~(3)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.

3835

Table 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.~~Contents

(4)Total proceeds from CERC’s February 2023 issuances of senior notes, net of transaction expenses and fees, of approximately $1.2 billion were used for general corporate purposes, including the repayment of (i) all or a portion of CERC’s outstanding 0.700% senior notes due 2023, (ii) all or a portion of CERC’s outstanding floating rate senior notes due 2023 and (iii) a portion of CERC’s outstanding commercial paper balances.

(5)Total proceeds, net of issuance premiums, transaction expenses and fees, of approximately $308 million, which includes approximately $3 million of accrued interest, were used for general corporate purposes, including repayment of all or a portion of CERC’s outstanding $500 million term loan due February 2024.

(6)Issued by SIGECO.

(7)Total proceeds from SIGECO’s March 2023 issuances of first mortgage bonds, net of transaction expenses and fees, of approximately $179 million were used for general corporate purposes, including repaying short-term debt and refunding long-term debt at maturity or otherwise.

(8)Total proceeds, net of transaction expenses and fees, of approximately $250 million were used for general corporate purposes, including the repayment of CenterPoint Energy’s outstanding commercial paper balances. The full outstanding amount of the term loan, including accrued and unpaid interest, was repaid in March 2023 and, following the repayment, the term loan agreement was terminated.

(9)Issued by the Securitization Subsidiary. Scheduled final payment dates are November 15, 2036 and May 15, 2041. The SIGECO Securitization Bonds will be repaid over time through a securitization charge imposed on retail electric customers in SIGECO’s service territory. See Notes 1 and 6 for further details.

(10)Total proceeds from the Securitization Subsidiary’s June 2023 issuance of SIGECO Securitization Bonds, net of transaction expenses and fees, of approximately $337 million were used to pay SIGECO the purchase price of the securitization property. SIGECO will use the net proceeds from the sale of the securitization property (after payment of upfront financing costs) to reimburse or pay for qualified costs approved by the IURC related to the planned retirement of its A.B. Brown 1 and 2 coal-powered generation units.

In April 2023, SIGECO executed a remarketing agreement, subject to standard conditions precedent, to remarket five series of tax-exempt debt issued by the Indiana Finance Authority, and secured by SIGECO first mortgage bonds, of approximately $148 million, comprised of: (i) $107 million aggregate principal amount of Environmental Improvement Refunding Revenue Bonds, Series 2013, originally issued by the Indiana Finance Authority on April 26, 2013, and (ii) $41 million aggregate principal amount of Environmental Improvement Refunding Revenue Bonds, Series 2014, originally issued by the Indiana Finance Authority on September 24, 2014, which closed on May 1, 2023. SIGECO expects to remarket an additional $38 million of tax-exempt debt at then market rates due to mandatory purchase or mandatory tender for purchase provisions by the end of 2023.

Debt Repayments and Redemptions. During the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, the following debt instruments were repaid at maturity or redeemed prior to maturity with proceeds received from the ~~sale of Energy Transfer units~~Texas securitization discussed further in Note ~~10:~~6 or through the issuance of new debt:

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

Registrant

Repayment/Redemption Date

Debt Instrument

Aggregate Principal Amount

Interest Rate

Maturity Date

(in millions)

CERC

March 2023

Term Loan (3)

500

SOFR (2) + 0.70%

2023

CERC

March 2023

Senior Notes

700

0.70%

2023

CERC

March 2023

Floating Rate Senior Notes

575

Three-month LIBOR plus 0.5%

2023

CERC

May 2023

Term Loan (4)

500

SOFR (2) + 0.85%

2024

Total CERC

2,275

CenterPoint Energy (1)

January 2023

First Mortgage Bonds

4.00%

2044

CenterPoint Energy

March 2023

Term Loan (3)

250

SOFR (2) + 1.50%

2023

Total CenterPoint Energy

2,536

(1)~~In January~~ On December 16, 2022, ~~CERC~~SIGECO provided notice of ~~partial~~ redemption and on January ~~31, 2022, CERC~~17, 2023, SIGECO redeemed ~~a portion ($425 million) of the outstanding $1 billion~~$11 million aggregate principal amount of ~~the series~~SIGECO’s outstanding first mortgage bonds due 2044 at a redemption price equal to 100% of the principal amount of the first mortgage bonds to be redeemed plus accrued and unpaid interest onthereon, if any, to, but excluding, the ~~principal~~redemption date.

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

(3) The full outstanding 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~~term loan, including accrued and unpaid interest, was repaid in March 2023 and, following the repayment, the term loan agreement was terminated.

(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~~ The full outstanding ~~$500 million aggregate principal~~ amount of the ~~series at a redemption price equal to 100% of the principal amount, plus~~term loan, including accrued and unpaid interest, ~~of approximately $6 million,~~was repaid in May 2023 and, following 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~~repayment, 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.~~term loan agreement was terminated.

Credit Facilities.

The Registrants had the following revolving credit facilities as of ~~September~~June 30, ~~2022:~~2023:

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


Execution Date	Registrant	Size of Facility		Draw Rate of SOFR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of June 30, 2023 (2)	Termination Date
		(in millions)
December 6, 2022	CenterPoint Energy	$	2,400	1.500%	65.0%	(3)	60.8%	December 6, 2027
December 6, 2022	CenterPoint Energy (4)	250		1.125%	65.0%		47.1%	December 6, 2027

December 6, 2022	Houston Electric	300		1.250%	67.5%	(3)	52.6%	December 6, 2027
December 6, 2022	CERC	1,050		1.125%	65.0%		42.2%	December 6, 2027
	Total	$	4,000

(1)Based on current credit ratings.

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

(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.

(4)

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 restatedThis credit ~~agreement dated as of February 4, 2021. VUH did not incur any penalties in connection with the early termination.~~facility was issued by SIGECO.

The Registrants, including the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of ~~September~~June 30, ~~2022.~~2023.

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


		September 30, 2022								December 31, 2021										June 30, 2023								December 31, 2022
Registrant	Registrant	Loans		Letters of Credit		Commercial Paper (1)		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper (1)		Weighted Average Interest Rate		Registrant		Loans		Letters of Credit		Commercial Paper (2)		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper (2)		Weighted Average Interest Rate
		(in millions, except weighted average interest rate)																	(in millions, except weighted average interest rate)
CenterPoint Energy	CenterPoint Energy	$	—	$	11	$	454	3.22	%	$	—	$	11	$	1,400	0.34	%	CenterPoint Energy		$	—	$	11	$	1,655	5.46	%	$	—	$	11	$	1,770	4.71	%
CenterPoint Energy ~~(2)~~(1)	CenterPoint Energy ~~(2)~~(1)	—		—		—		—	%	—		—		350		0.21	%	CenterPoint Energy ~~(2)~~(1)		—		—		—		—	%	—		—		—		—	%

Houston Electric	Houston Electric	—		—		—		—	%	—		—		—		—	%	Houston Electric		—		—		—		—	%	—		—		—		—	%
CERC	CERC	—		—		575		3.38	%	—		—		899		0.26	%	CERC		—		1		—		—	%	—		—		805		4.67	%
Total	Total	$	—	$	11	$	1,029			$	—	$	11	$	2,649			Total		$	—	$	12	$	1,655			$	—	$	11	$	2,575

(1)This credit facility was issued by SIGECO.

(2)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. Neither Houston Electric ~~does not have~~nor SIGECO has 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~~June 30, ~~2022,~~2023, Houston Electric’s assets were subject to liens securing approximately ~~$6.3~~$7.1 billion of general mortgage bonds outstanding under the General Mortgage, 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. AsHouston Electric may issue additional general mortgage bonds on the basis of ~~September 30, 2022,~~retired bonds, 70% of property additions or cash deposited with the trustee. Houston Electric could issue approximately ~~$4.3~~$4.7 billion of additional general mortgage bonds on the basis of retired bonds and 70% of property ~~additions.~~additions as of June 30, 2023. No first

mortgage bonds are outstanding under the M&DOT, and Houston Electric is contractually obligated to not issue any additional first mortgage bonds under the M&DOT and is undertaking actions to release the lien of the M&DOT and terminate the M&DOT.

As of June 30, 2023, SIGECO had approximately $457 million aggregate principal amount of first mortgage bonds outstanding. Generally, all of SIGECO’s real and tangible property is subject to the lien of SIGECO’s mortgage indenture which was amended and restated effective as of January 1, 2023. As of June 30, 2023, SIGECO was permitted to issue additional bonds under its mortgage indenture up to 70% of then currently unfunded property additions and approximately $1.3 billion of additional first mortgage bonds could be issued on this basis.

Other. As of ~~September~~June 30, ~~2022,~~2023, certain financial institutions agreed to issue, from time to time, up to ~~$20~~$5 million of letters of credit on behalf of Vectren and certain of its subsidiaries in exchange for customary fees. As of ~~September~~June 30, ~~2022,~~2023, such financial institutions had issued less than $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 %


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
CenterPoint Energy (1)	46	%	22	%	29	%	26	%

Houston Electric (2)	21	%	21	%	22	%	21	%
CERC (3) (4)	20	%	4	%	22	%	23	%

(1)CenterPoint Energy’s higher effective tax rate ~~on income from continuing operations~~ for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the same periods ended ~~September~~June 30, ~~2021~~2022 was primarily ~~driven~~due to tax impacts of the sale of Energy Systems Group which is partially offset by the ~~impact~~absence 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.~~2022.

(2)Houston Electric’s higher effective tax rate for the ~~three and nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the same period in ~~2021~~2022 was primarily driven by ~~a decrease~~an increase in ~~the amount of amortization of the net regulatory EDIT liability.~~state income taxes.

(3)CERC’s higher effective tax rate for the three months ended ~~September~~June 30, ~~2022~~2023 compared to the same period ended ~~September~~June 30, ~~2021~~2022 was primarily driven by the ~~impact of the non-deductible goodwill associated with the sale of the Natural Gas businesses~~increase in ~~Arkansas~~income from continuing operations in 2023 while favorable permanent tax adjustments and ~~Oklahoma, and a decrease in~~ EDIT amortization ~~of the net regulatory EDIT liability.~~remained consistent.

(4)CERC’s ~~higher~~lower effective tax rate for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the same period ended ~~September~~June 30, ~~2021~~2022 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~~decreased amortization of the ~~net~~EDIT 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.liability.

CenterPoint Energy reported a net uncertain tax liability, inclusive of interest and penalties, of $5$29 million as of ~~September~~June 30, ~~2022.~~2023. The Registrants believe that it is reasonably possible that ~~a decrease of less than $1 million~~there will be no change in unrecognized tax benefits, ~~may occur~~including penalties and interest, 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.~~ 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~~have been audited and settled with 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~~June 30, ~~2022~~2023 and December 31, ~~2021.~~2022. 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.

4138

On February 1, 2023, Indiana Electric entered into an amended and restated BTA to purchase the 191 MW Posey Solar project for a fixed purchase price over the anticipated 35-year life. On February 7, 2023, Indiana Electric filed a CPCN with the IURC to approve the amended BTA. With the passage of the IRA, Indiana Electric can now pursue PTCs for solar projects. Indiana Electric has filed an updated CPCN with a request that project costs, net of PTCs, be recovered in rate base, through base rates or the CECA mechanism, depending on which provides more timely recovery. The Posey Solar project is expected to be placed in service in 2025.

On January 11, 2023, the IURC issued an order approving the settlement agreement granting Indiana Electric a CPCN to purchase and acquire the 130 MW Pike County solar project through a BTA and approved the estimated cost. The IURC also designated the project as a clean energy project as well as approved the proposed levelized rate and associated ratemaking and accounting treatment. The project is expected to be placed in service by 2025.

As of ~~September~~June 30, ~~2022,~~2023, other than discussed below, undiscounted minimum purchase obligations are approximately:


		CenterPoint Energy				CERC			CenterPoint Energy						CERC
		Natural Gas and Coal Supply		Other (1)		Natural Gas Supply			Natural Gas Supply		Electric Supply (1)		Other (2)		Natural Gas Supply
		(in millions)							(in millions)
Remaining three months of 2022		$	343	$	79	$	289
2023		1,046		567		923
Remaining six months of 2023								Remaining six months of 2023	$	322	$	87	$	111	$	318
2024	2024	898		385		855		2024	671		161		191		666
2025	2025	669		63		627		2025	572		703		56		569
2026	2026	510		33		474		2026	487		103		39		483
2027	2027	442		74		406		2027	412		105		—		408
2028 and beyond		2,135		571		2,019
2028								2028	368		68		—		364
2029 and beyond								2029 and beyond	1,707		718		392		1,682

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

(2)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)

On May 21, 2023, CenterPoint Energy, through Vectren Energy Services, entered into the Equity Purchase Agreement to sell Energy Systems Group. The sale closed on June 30, 2023. See Note 3 for further information.

In the normal course of business ~~Energy Systems Group~~ ~~enters into contracts requiring it~~prior 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~~consummation of the ~~surety bonds and is limited to the level of uncompleted work under the contracts. As of September~~transaction on June 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, 2022,2023, CenterPoint Energy, primarily through Vectren, ~~has~~ issued parent company level guarantees supporting Energy Systems Group’s obligations. When Energy Systems Group was wholly owned by CenterPoint Energy, these guarantees did not represent incremental consolidated obligations, but rather, these guarantees represented guarantees of Energy Systems Group’s obligations to allow it to conduct business without posting other forms of assurance. For those obligations where potential exposure can be estimated, management estimates the maximum exposure under these guarantees to be approximately ~~$534~~$519 million as of ~~September~~June 30, ~~2022.~~2023. 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~~were issued prior to the sale of Energy Systems Group in support of federal operations and maintenance projects for which a maximum exposure cannot be estimated based on the nature of the projects.

Under the terms of the Equity Purchase Agreement, ESG Holdings Group must generally use reasonable best efforts to replace existing CenterPoint Energy guarantees with credit support provided by a party other than CenterPoint Energy as of and after the closing of the transaction. The Equity Purchase Agreement also requires certain protections to be provided for any damages incurred by CenterPoint Energy in relation to these guarantees not released by closing. No additional guarantees were provided by CenterPoint Energy in favor of Energy Systems Group subsequent to the closing of the sale on June 30, 2023.

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.

~~(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~~ believes that, from 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~~Systems 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’s inception in 1994 to the closing of the sale of ~~the~~ Energy ~~Services Disposal~~Systems Group on June ~~1, 2020, CERC Corp. issued~~30, 2023, Energy Systems Group had a history of generally meeting its performance obligations and energy savings 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.

its installed products operated effectively. CenterPoint Energy ~~and CERC~~ recorded no amounts on ~~their respective~~its Condensed Consolidated Balance Sheets as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021~~2022 related to its obligation under the ~~performance of these~~outstanding guarantees.

~~(d)~~ (c)Legal, Environmental and Other Matters

Legal Matters

Litigation Related to the February 2021 Winter Storm Event. Various legal ~~matters~~proceedings are still ~~proceeding~~pending against numerous entities 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~~Event, including against CenterPoint Energy, Utility Holding, LLC, ~~and~~ Houston Electric, ~~along with numerous other entities, have been named as defendants.~~and CERC. 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 during the storm and their compliance with NERC, ERCOT and PUCT rules and directives. Additionally, like other natural gas market participants, CERC has been named in litigation alleging gas market manipulation.

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,~~REPs, 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~~

Substantially all of the litigation is ~~now~~or will be consolidated in Texas state court in Harris County, Texas, as part of ~~a multi-district litigation proceeding.~~an MDL proceeding, with one case currently pending in justice court in Harris County. The judge overseeing the ~~multi-district litigation has~~MDL issued an initial case management order and stayed all proceedings and ~~discovery, including discovery related to damages.~~discovery. Per the case management order, the judge ~~will first entertain~~entertained dispositive motions in five representative or “bellwether” ~~cases;~~cases and, in late January 2023, issued rulings on them. The judge ruled that ERCOT has sovereign immunity as a governmental entity and dismissed the ~~judge~~suits against it. In a recent opinion in an unrelated matter, the Texas Supreme Court held ~~hearings on them in mid-October and will likely rule on them later in 2022, which~~that ERCOT is entitled to sovereign immunity. This ruling will ~~likely~~apply to claims against ERCOT in the MDL. The MDL judge also dismissed all claims against the natural gas defendants (which lists of natural gas defendants incorrectly included Utility Holding, LLC), and the REP defendants and some causes of action against the other defendants. As to the TDU and generator defendants, the MDL judge dismissed some causes of action but denied the motions to dismiss claims for negligence, gross negligence, and nuisance, which denial the TDU defendants and generator defendants are asking the court of appeals to overturn. The court of appeals has granted the request for oral argument in the TDU mandamus proceeding and is expected to hear oral argument in the third quarter of 2023. The MDL judge has allowed plaintiffs to file amended petitions and is going to entertain a second round of initial motions in the five bellweather cases, but otherwise the cases remain stayed as the MDL judge addresses additional preliminary issues.

Following the initial rulings and around the two-year anniversary of the February 2021 Winter Storm Event, there were voluminous amendments, non-suits and re-filings of pending lawsuits, and the filing of new lawsuits, and there continue to be ~~appealed. Until~~amendments. As such, the ~~judge rules~~pleadings are still being settled and the precise number of cases and claims against particular defendants and in total is still being determined. As of June 30, 2023, there are approximately 225 pending lawsuits that are in or will be added to the MDL proceeding related to the February 2021 Winter Storm Event, and CenterPoint Energy and Houston Electric, along with numerous other entities, have been named as defendants in approximately 155 of those lawsuits. A putative class action on ~~those motions~~behalf of everyone who received electric power via the ERCOT grid and ~~any appeals~~sustained a power outage between February 10, 2021 and February 28, 2021 is also pending against CenterPoint Energy, Houston Electric, and numerous other defendants. Additionally, Utility Holding, LLC is currently named as a defendant in approximately six lawsuits in which CenterPoint Energy and/or Houston Electric are also named as defendants. CenterPoint Energy expects that the claims against Utility Holding, LLC will ultimately be dismissed in light of ~~such rulings are resolved, further proceedings and discovery will likely remain stayed.~~the judge’s initial rulings. 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~~also 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~~

In February 2023, twelve lawsuits were filed in state district court in Harris County and Tom Green County, Texas, against dozens of gas market participants in Texas, including natural gas producers, processors, pipelines, marketers, sellers, traders, gas utilities, and financial institutions. Plaintiffs named CERC as one such defendant, along with “CenterPoint Energy Services, Inc.,” incorrectly identifying it as CERC’s parent company (CenterPoint Energy previously divested CES). One lawsuit filed in Harris County is a putative class action on behalf of two classes of electric and natural gas customers (those who experienced a

loss of electricity and/or natural gas, and those who were charged securitization-related surcharges on a utility bill or were otherwise charged higher rates for electricity and/or gas during the February 2021 Winter Storm Event), potentially including millions of class members. Two other lawsuits (one filed in Harris County and one in Tom Green County) are brought by an entity that purports to be an assignee of claims by tens of thousands of persons and entities ~~include~~that have assigned claims to the ~~United States Congress, FERC, NERC, Texas RE, ERCOT, Texas government entities~~plaintiff. These, and ~~officials such~~nine other similar lawsuits filed in Harris County, generally allege that the defendants engaged in gas market manipulation and price gouging, including by intentionally withholding, suppressing, or diverting supplies of natural gas in connection with the February 2021 Winter Storm Event, Winter Storm Elliott, and other severe weather conditions, and through financial market manipulation. Plaintiffs allege that this manipulation impacted gas supply and prices as well as the market, supply, and price of electricity in Texas ~~Governor’s office, the Texas Legislature, the PUCT, the City of Houston~~and caused blackouts and other ~~municipal~~damage. Plaintiffs assert claims for tortious interference with existing contract, private nuisance, and ~~county entities~~unjust enrichment, and allege a broad array of injuries and damages, including personal injury, property damage, and harm from certain costs being securitized and passed on to ratepayers. The lawsuits do not specify the amount of damages sought, but seek broad categories of actual, compensatory, statutory, consequential economic, and punitive damages; restitution and disgorgement; pre- and post-judgment interest; costs and attorneys’ fees; and other relief. As of June 30, 2023, most of the lawsuits have not been served, but the three cases in ~~Houston Electric’s service territory. Additionally, CenterPoint Energy~~which defendants were served were tagged for transfer to the existing MDL proceeding referenced above. The plaintiffs in those three cases filed motions to remand the lawsuits back to their original trial courts and out of the MDL. On June 28, 2023, the judge overseeing the MDL heard oral arguments on the motions to remand, but did not state when she would render her ruling. Regardless of whether the cases remain within the MDL, CERC ~~have responded~~intends to ~~inquiries from several state Attorneys General.~~vigorously defend itself against the claims raised, including by raising jurisdictional challenges to the plaintiffs’ claims.

To date, there have not been demands, quantification, disclosure or discovery of damages by any party to any of the ~~litigation~~above legal matters 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. Given the nature of certain of the recent allegations, however, it is possible that the insurers for third party bodily injury and property damage claims could dispute coverage for other types of damage that may be alleged by plaintiffs. CenterPoint Energy and its subsidiaries intend to continue to pursue any and all available insurance coverage for all of these matters.

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					June 30, 2023
		CenterPoint Energy		CERC			CenterPoint Energy		CERC
		(in millions, except years)					(in millions, except years)
Amount accrued for remediation	Amount accrued for remediation	$	16	$	14	Amount accrued for remediation	$	17	$	15
Minimum estimated remediation costs	Minimum estimated remediation costs	12		11		Minimum estimated remediation costs	12		11
Maximum estimated remediation costs	Maximum estimated remediation costs	51		44		Maximum estimated remediation costs	51		44
Minimum years of remediation	Minimum years of remediation	5		5		Minimum years of remediation	5		5
Maximum years of remediation	Maximum years of remediation	50		50		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.

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~~filed timely extension requests 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.~~pond; however, the Culley East pond was taken out of service on May 1, 2023, so there is no longer a need for an extension at Culley. 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. On November 1, 2022, Indiana Electric filed for a CPCN to recover federally mandated costs associated with closure of the Culley East Pond, its third and final ash pond. Indiana Electric is also seeking accounting and ratemaking relief for the project, and on June 8, 2023, Indiana Electric filed a revised CPCN for recovery of the federally mandated ash pond costs. The project costs are estimated to be approximately $50 million, inclusive of overheads.

On March 18, 2023, the EPA proposed amendments to the CCR rule that would, if finalized, apply closure requirements for inactive surface impoundments located at inactive facilities (legacy CCR surface impoundments) and CCR management units located at regulated CCR facilities. CenterPoint Energy is currently reviewing this proposal.

As of ~~September~~June 30, ~~2022,~~2023, CenterPoint Energy has recorded an approximate ~~$92~~$109 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,~~2020, 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

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 common 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.awards. 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.

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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions, except per share and share amounts)									(in millions, except per share and share amounts)
Numerator:	Numerator:									Numerator:
Income from continuing operations	Income from continuing operations	$	202	$	150	$	923	$	630	Income from continuing operations	$	118	$	190	$	443	$	721
Less: Preferred stock dividend requirement (Note 18)	Less: Preferred stock dividend requirement (Note 18)	13		23		37		82		Less: Preferred stock dividend requirement (Note 18)	12		11		24		24

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	Income available to common shareholders - basic and diluted	$	189	$	195	$	886	$	750	Income available to common shareholders - basic and diluted	$	106	$	179	$	419	$	697
Denominator:	Denominator:									Denominator:
Weighted average common shares outstanding - basic	Weighted average common shares outstanding - basic	629,509,000		604,607,000		629,374,000		580,819,000		Weighted average common shares outstanding - basic	631,057,000		629,475,000		630,685,000		629,306,000
Plus: Incremental shares from assumed conversions:	Plus: Incremental shares from assumed conversions:									Plus: Incremental shares from assumed conversions:
Restricted stock	Restricted stock	3,559,000		4,775,000		3,559,000		4,775,000		Restricted stock	1,948,000		2,188,000		2,345,000		2,188,000

Series C Preferred Stock		—		—		—		15,809,000

Weighted average common shares outstanding - diluted	Weighted average common shares outstanding - diluted	633,068,000		609,382,000		632,933,000		601,403,000		Weighted average common shares outstanding - diluted	633,005,000		631,663,000		633,030,000		631,494,000

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:	Earnings Per Common Share:									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	Basic Earnings Per Common Share	$	0.30	$	0.32	$	1.41	$	1.29	Basic Earnings Per Common Share	$	0.17	$	0.28	$	0.66	$	1.11
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	Diluted Earnings Per Common Share	$	0.30	$	0.32	$	1.40	$	1.25	Diluted Earnings Per Common Share	$	0.17	$	0.28	$	0.66	$	1.10

(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~~June 30, ~~2022,~~2023, 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,

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 through June 30, 2023, the date of the sale of 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:~~follows:

CenterPoint Energy


		Three Months Ended September 30,										Three Months Ended June 30,
		2022			2021							2023		2022
		Revenues from External Customers			Net Income (Loss)		Revenues from External Customers			Net Income (Loss)				Revenues from External Customers			Net Income (Loss)		Revenues from External Customers			Net Income (Loss)
		(in millions)										(in millions)
Electric	Electric	$	1,146	(1)	$	234	$	1,056	(1)	$	185		Electric	$	1,037	(1)	$	180	$	1,053	(1)	$	173
Natural Gas	Natural Gas	692			(10)		619			5			Natural Gas	764			35		818			28
Corporate and Other	Corporate and Other	65			(22)		74			(40)			Corporate and Other	74			(97)		73			(11)
Continuing Operations		$	1,903		202		$	1,749		150
Discontinued Operations, net					—					68
Consolidated	Consolidated				$	202				$	218		Consolidated	$	1,875		$	118	$	1,944		$	190

		Nine Months Ended September 30,										Six Months Ended June 30,
		2022			2021							2023		2022
		Revenues from External Customers			Net Income		Revenues from External Customers			Net Income (Loss)				Revenues from External Customers			Net Income (Loss)		Revenues from External Customers			Net Income
		(in millions)										(in millions)
Electric	Electric	$	3,092	(1)	$	489	$	2,823	(1)	$	385		Electric	$	1,989	(1)	$	303	$	1,946	(1)	$	255
Natural Gas	Natural Gas	3,334			416		3,022			308			Natural Gas	2,539			269		2,642			426
Corporate and Other	Corporate and Other	184			18		193			(63)			Corporate and Other	126			(129)		119			40

Continuing Operations		$	6,610		923		$	6,038		630
Discontinued Operations, net					—					202
Consolidated	Consolidated				$	923				$	832		Consolidated	$	4,654		$	443	$	4,707		$	721

(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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Affiliates of NRG	Affiliates of NRG	$	327	$	285	$	797	$	672	Affiliates of NRG	$	229	$	245	$	456	$	470
Affiliates of Vistra Energy Corp.	Affiliates of Vistra Energy Corp.	153		128		372		303		Affiliates of Vistra Energy Corp.	112		114		226		219


		Total Assets					Total Assets
		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in millions)					(in millions)
Electric	Electric	$	18,524	$	16,548	Electric	$	20,302	$	19,024
Natural Gas	Natural Gas	16,796		16,270		Natural Gas	16,745		18,043

Corporate and Other, net of eliminations (1)	Corporate and Other, net of eliminations (1)	1,399		2,523		Corporate and Other, net of eliminations (1)	1,050		1,479

Continuing Operations		36,719		35,341
Assets Held for Sale		—		2,338
Consolidated	Consolidated	$	36,719	$	37,679	Consolidated	$	38,097	$	38,546

(1)Total assets included pension and other postemployment-related regulatory assets of ~~$424~~$385 million and ~~$427~~$405 million as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, 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,													Six Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Cash Payments/Receipts:	Cash Payments/Receipts:													Cash Payments/Receipts:
Interest, net of capitalized interest	Interest, net of capitalized interest	$	376	$	188	$	67	$	427	$	172	$	96	Interest, net of capitalized interest	$	317	$	128	$	82	$	219	$	96	$	41
Income tax payments (refunds), net		340		113		3		(47)		—		(11)
Income tax payments, net														Income tax payments, net	154		1		34		267		130		5
Non-cash transactions:	Non-cash transactions:													Non-cash transactions:
Accounts payable related to capital expenditures	Accounts payable related to capital expenditures	333		197		145		290		208		124		Accounts payable related to capital expenditures	297		164		133		352		221		147
ROU assets obtained in exchange for lease liabilities (1)	ROU assets obtained in exchange for lease liabilities (1)	1		—		—		2		—		—		ROU assets obtained in exchange for lease liabilities (1)	3		1		—		1		—		—

(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							June 30, 2023						December 31, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Cash and cash equivalents (1)	Cash and cash equivalents (1)	$	114	$	115	$	1	$	230	$	214	$	15	Cash and cash equivalents (1)	$	214	$	62	$	1	$	74	$	75	$	—
Restricted cash included in Prepaid expenses and other current assets	Restricted cash included in Prepaid expenses and other current assets	16		12		—		24		19		—		Restricted cash included in Prepaid expenses and other current assets	18		12		—		17		13		—

Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	130	$	127	$	1	$	254	$	233	$	15	Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	232	$	74	$	1	$	91	$	88	$	—

(1)~~Houston Electric’s~~ Cash and cash equivalents related to VIEs as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021~~2022 included ~~$110~~$63 million and ~~$92~~$75 million, respectively, ~~of cash related to the Bond Companies.~~at CenterPoint Energy and $62 million and $75 million, respectively, at Houston Electric.

(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							June 30, 2023						December 31, 2022
		Houston Electric			CERC			Houston Electric			CERC				Houston Electric			CERC			Houston Electric			CERC
		(in millions, except interest rates)													(in millions, except interest rates)
Money pool investments (borrowings) (1)	Money pool investments (borrowings) (1)	$	360		$	—		$	(512)		$	(224)		Money pool investments (borrowings) (1)	$	(110)		$	417		$	(642)		$	—
Weighted average interest rate	Weighted average interest rate	3.25		%	3.25		%	0.34		%	0.34		%	Weighted average interest rate	5.50		%	5.50		%	4.75		%	4.75		%

(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


	Three Months Ended June 30,								Six Months Ended June 30,
	2023				2022				2023				2022
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Corporate service charges	$	40	$	56	$	37	$	51	$	75	$	106	$	76	$	109
Net affiliate service charges (billings)	(3)		3		(9)		9		(6)		6		(15)		15

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


		Three Months Ended September 30,								Nine Months Ended September 30,									Three Months Ended June 30,								Six Months Ended June 30,
		2022				2021				2022				2021					2023				2022				2023				2022
		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
		(in millions)																	(in millions)
Cash dividends paid to parent	Cash dividends paid to parent	$	74	$	13	$	—	$	—	$	141	$	124	$	—	$	—	Cash dividends paid to parent	$	109	$	107	$	30	$	72	$	160	$	311	$	67	$	111
Cash dividend paid to parent related to the sale of the Arkansas and Oklahoma Natural Gas businesses	Cash dividend paid to parent related to the sale of the Arkansas and Oklahoma Natural Gas businesses	—		—		—		—		—		720		—		—		Cash dividend paid to parent related to the sale of the Arkansas and Oklahoma Natural Gas businesses	—		—		—		—		—		—		—		720
Cash contribution from parent	Cash contribution from parent	—		—		—		—		1,143		125		—		—		Cash contribution from parent	—		500		506		125		650		500		1,143		125
Net assets acquired in the Restructuring ~~(1)~~	Net assets acquired in the Restructuring ~~(1)~~	—		—		—		—		—		2,345		—		—		Net assets acquired in the Restructuring ~~(1)~~	—		—		—		2,345		—		—		—		2,345
Non-cash capital contribution from parent in payment for property, plant and equipment below	Non-cash capital contribution from parent in payment for property, plant and equipment below	—		—		—		—		38		54		—		—		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	Cash paid to parent for property, plant and equipment below	—		—		—		—		65		61		—		—		Cash paid to parent for property, plant and equipment below	—		—		13		13		—		—		65		61
Property, plant and equipment from parent ~~(2)~~(1)	Property, plant and equipment from parent ~~(2)~~(1)	—		—		—		—		103		115		—		—		Property, plant and equipment from parent ~~(2)~~(1)	—		—		13		13		—		—		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

(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.


	Dividends Declared Per Share								Dividends Paid Per Share
	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022		2023		2022		2023		2022
Common Stock	$	0.190	$	0.170	$	0.190	$	0.170	$	0.190	$	0.170	$	0.380	$	0.340
Series A Preferred Stock	—		—		—		—		—		—		30.625		30.625

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


	Liquidation Preference Per Share		Shares Outstanding as of		Outstanding Value as of
			June 30, 2023	December 31, 2022	June 30, 2023		December 31, 2022
	(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,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in millions)									(in millions)
Series A Preferred Stock	Series A Preferred Stock	$	13	$	12	$	37	$	37	Series A Preferred Stock	$	12	$	11	$	24	$	24
Series B Preferred Stock		—		11		—		45

Total income allocated to preferred shareholders	Total income allocated to preferred shareholders	$	13	$	23	$	37	$	82	Total income allocated to preferred shareholders	$	12	$	11	$	24	$	24

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, then President and Chief Executive Officer of CenterPoint Energy, dated July 20, 2021. ~~Under the terms of~~Pursuant to the retention incentive agreement, Mr. Lesar ~~will receive~~received equity-based awards under CenterPoint Energy’s LTIP covering a total of 1 million shares of Common Stock (Total Stock Award) ~~to be~~which were granted in multiple annual awards. Mr. Lesar received 400 thousand restricted stock units in July 2021 that ~~will vest~~vested in December 2022 and 400 thousand restricted stock units and 200 thousand restricted stock units in February 2022 and February 2023, respectively, 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 ofthat death, disability, termination without cause or resignation for good reason, as defined in the retention incentive agreement, ~~that occurs~~had occurred prior to the full Total Stock Award being awarded, CenterPoint Energy ~~will pay~~would have paid 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~~would have been redeemable for cash

prior to being awarded upon events that ~~are~~were not probable at the grant date, the equity associated with ~~the~~any unawarded equity-based awards ~~will be~~were classified as Temporary Equity as of December 31, 2022 on CenterPoint Energy’s Condensed Consolidated Balance Sheets. As of June 30, 2023, all restricted stock units have been awarded to Mr. Lesar and no amounts are reflected in 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 June 30,
															2023						2022
															CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
															(in millions)
Beginning Balance														Beginning Balance	$	(32)	$	—	$	15	$	(62)	$	—	$	10
Other comprehensive income (loss) before reclassifications:														Other comprehensive income (loss) before reclassifications:
Remeasurement of pension and other postretirement plans														Remeasurement of pension and other postretirement plans	—		—		—		(34)		—		—

Amounts reclassified from accumulated other comprehensive income (loss):														Amounts reclassified from accumulated other comprehensive income (loss):
Prior service cost (1)														Prior service cost (1)	—		—		—		1		—		—
Actuarial losses (1)														Actuarial losses (1)	—		—		—		1		—		—
Settlement (2)														Settlement (2)	—		—		—		13		—		—

Tax benefit (expense)														Tax benefit (expense)	—		—		—		(4)		—		—
Net current period other comprehensive income (loss)														Net current period other comprehensive income (loss)	—		—		—		(23)		—		—
Ending Balance														Ending Balance	$	(32)	$	—	$	15	$	(85)	$	—	$	10

		Three Months Ended September 30,													Six Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Beginning Balance	Beginning Balance	$	(85)	$	—	$	10	$	(85)	$	—	$	10	Beginning Balance	$	(31)	$	—	$	16	$	(64)	$	—	$	10
Other comprehensive income (loss) before reclassifications:	Other comprehensive income (loss) before reclassifications:													Other comprehensive income (loss) before reclassifications:
Remeasurement of pension and other postretirement plans	Remeasurement of pension and other postretirement plans	(10)		—		—		—		—		—		Remeasurement of pension and other postretirement plans	—		—		—		(34)		—		—

Amounts reclassified from accumulated other comprehensive income (loss):	Amounts reclassified from accumulated other comprehensive income (loss):													Amounts reclassified from accumulated other comprehensive income (loss):
Prior service cost (1)	Prior service cost (1)	—		—		—		1		—		—		Prior service cost (1)	(1)		—		(1)		1		—		—
Actuarial losses (1)	Actuarial losses (1)	2		—		—		1		—		—		Actuarial losses (1)	—		—		—		2		—		—
Settlement (2)	Settlement (2)	1		—		—		3		—		—		Settlement (2)	—		—		—		13		—		—
Reclassification of deferred loss from cash flow hedges realized in net income	Reclassification of deferred loss from cash flow hedges realized in net income	—		—		—		1		—		—		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)	Tax benefit (expense)	5		—		—		(2)		—		—		Tax benefit (expense)	—		—		—		(4)		—		—
Net current period other comprehensive income (loss)	Net current period other comprehensive income (loss)	(19)		—		—		10		—		—		Net current period other comprehensive income (loss)	(1)		—		(1)		(21)		—		—
Ending Balance	Ending Balance	$	(83)	$	—	$	10	$	(80)	$	—	$	10	Ending Balance	$	(32)	$	—	$	15	$	(85)	$	—	$	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.

(19) Leases

In 2021, Houston Electric entered into a temporary short-term lease and a long-term ~~lease, each~~leases for mobile generation. The short-term lease agreement ~~allows~~allowed 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. As of December 31, 2022, the short-term lease agreement has expired and all mobile generation assets are leased under the long-term lease agreement. Per Houston Electric’s ~~short term~~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~~net of amounts recovered in rates, $104 million and ~~$20~~$103 million as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively.

~~Houston Electric took delivery of an additional 32 MW and 160~~The long-term lease agreement includes up to 505 MW of TEEEF, ~~under the long-term~~all of which was delivered as of December 31, 2022, triggering 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.~~commencement at delivery, with an initial term ending in 2029 for all TEEEF leases. 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~~June 30, ~~2022~~2023 and December 31, ~~2021~~2022 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~~June 30, ~~2022,~~2023, Houston Electric has secured a first lien on ~~all~~ the ~~generation equipment long-term leases and no amount of~~assets leased under the prepayment agreement, except for assets with lease payments ~~made~~totaling $113 million. The $113 million prepayment is being held in an escrow account, not controlled by Houston Electric, ~~under long-term leases were held in escrow.~~and the funds will be released when a first lien can be secured for Houston Electric. Expenses associated with the long-term lease, including depreciation expense on the right of use asset and carrying costs, are deferred to a regulatory asset and totaled, ~~$41~~net of amounts recovered in rates, $106 million and $1$60 million as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively. The long-term lease agreement ~~also~~ contains a termination clause that can be exercised in the event of material adverse regulatory actions. If the right to terminate is elected, subject to the satisfaction of certain conditions, 75% of Houston Electric’s prepaid lease costs that is attributable to the period from the effective date of termination to the end of the lease term would be refunded. In December 2022, the long-term lease agreement was amended to include a disallowance reimbursement clause that can be exercised in the event that any regulatory proceeding or settlement agreement results in a disallowance of Houston Electric’s recovery of deferred costs under either the long-term lease agreement, short-term lease agreement or any other quantifiable adverse financial impact to Houston Electric. If the disallowance reimbursement clause is exercised, 85% of such disallowance up to $53 million would be paid to Houston Electric. Any disallowance greater than $53 million would remain subject to the 75% limit set forth in the termination clause. For further discussion of the regulatory impacts, see Note 6.

Houston Electric will also incur variable costs throughout the lease term for the operation and maintenance of the generators. Lease costs, including variable and ROU asset amortization costs, are deferred to Regulatory assets as incurred as a recoverable cost under the 2021 Texas legislation. See Note 6 for further information regarding recovery of these deferred costs.

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							Three Months Ended June 30, 2023						Three Months Ended June 30, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Operating lease cost	Operating lease cost	$	2	$	—	$	—	$	2	$	—	$	1	Operating lease cost	$	1	$	—	$	1	$	2	$	—	$	—
Short-term lease cost	Short-term lease cost	39		39		1		54		54		—		Short-term lease cost	13		14		—		37		37		—
Variable lease cost		—		—		—		—		—		—

Total lease cost (1)	Total lease cost (1)	$	41	$	39	$	1	$	56	$	54	$	1	Total lease cost (1)	$	14	$	14	$	1	$	39	$	37	$	—

		Nine Months Ended September 30, 2022						Nine Months Ended September 30, 2021							Six Months Ended June 30, 2023						Six Months Ended June 30, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Operating lease cost	Operating lease cost	$	4	$	—	$	1	$	6	$	—	$	3	Operating lease cost	$	3	$	1	$	1	$	2	$	—	$	1
Short-term lease cost	Short-term lease cost	123		122		1		89		89		—		Short-term lease cost	13		13		—		84		83		—
Variable lease cost		—		—		—		—		—		—

Total lease cost (1)	Total lease cost (1)	$	127	$	122	$	2	$	95	$	89	$	3	Total lease cost (1)	$	16	$	14	$	1	$	86	$	83	$	1

(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.

5450

~~The components of lease~~Lease income ~~were~~was as follows:


		Three Months Ended September 30, 2022						Three Months Ended September 30, 2021							Three Months Ended June 30, 2023						Three Months Ended June 30, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Operating lease income	Operating lease income	$	1	$	1	$	1	$	1	$	1	$	1	Operating lease income	$	1	$	—	$	1	$	1	$	—	$	1
Variable lease income	Variable lease income	—		—		—		—		—		—		Variable lease income	—		—		—		1		—		—
Total lease income	Total lease income	$	1	$	1	$	1	$	1	$	1	$	1	Total lease income	$	1	$	—	$	1	$	2	$	—	$	1

		Nine Months Ended September 30, 2022						Nine Months Ended September 30, 2021							Six Months Ended June 30, 2023						Six Months Ended June 30, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Operating lease income	Operating lease income	$	4	$	1	$	2	$	4	$	1	$	2	Operating lease income	$	3	$	—	$	2	$	3	$	—	$	1
Variable lease income	Variable lease income	1		—		—		1		—		—		Variable lease income	1		—		—		1		—		—
Total lease income	Total lease income	$	5	$	1	$	2	$	5	$	1	$	2	Total lease income	$	4	$	—	$	2	$	4	$	—	$	1

Supplemental balance sheet information related to leases was as follows:


		September 30, 2022									December 31, 2021										June 30, 2023					December 31, 2022
		CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC						CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
		(in millions, except lease term and discount rate)																		(in millions, except lease term and discount rate)
Assets:	Assets:																					Assets:
Operating ROU assets (1)	Operating ROU assets (1)	$	15		$	—		$	6		$	22		$	1		$	12				Operating ROU assets (1)	$	16		$	7		$	5		$	19		$	6		$	5
Finance ROU assets (2)	Finance ROU assets (2)	367			367			—			179			179			—					Finance ROU assets (2)	574			574			—			621			621			—
Total leased assets	Total leased assets	$	382		$	367		$	6		$	201		$	180		$	12				Total leased assets	$	590		$	581		$	5		$	640		$	627		$	5

Liabilities:	Liabilities:																					Liabilities:
Current operating lease liability (3)	Current operating lease liability (3)	$	5		$	—		$	2		$	6		$	1		$	2				Current operating lease liability (3)	$	4		$	1		$	2		$	5		$	1		$	2
Non-current operating lease liability (4)	Non-current operating lease liability (4)	10			—			4			17			—			11					Non-current operating lease liability (4)	12			5			3			14			5			4
Total leased liabilities (5)	Total leased liabilities (5)	$	15		$	—		$	6		$	23		$	1		$	13				Total leased liabilities (5)	$	16		$	6		$	5		$	19		$	6		$	6

Weighted-average remaining lease term (in years) - operating leases	Weighted-average remaining lease term (in years) - operating leases	5			5.4			4.1			6.2			4.1			6.5					Weighted-average remaining lease term (in years) - operating leases	5.0			4.4			3.5			4.3			4.8			3.9
Weighted-average discount rate - operating leases	Weighted-average discount rate - operating leases	3.16		%	3.50		%	3.55		%	3.10		%	2.86		%	3.20		%			Weighted-average discount rate - operating leases	4.10		%	4.09		%	3.59		%	3.80		%	4.01		%	3.58		%
Weighted-average remaining lease term (in years) - finance leases	Weighted-average remaining lease term (in years) - finance leases	6.8			6.8			—			7.5			7.5			—					Weighted-average remaining lease term (in years) - finance leases	6.0			6.0			—			6.5			6.5			—
Weighted-average discount rate - finance leases	Weighted-average discount rate - finance leases	2.73		%	2.73		%	—			2.21		%	2.21		%	—					Weighted-average discount rate - finance leases	3.60		%	3.60		%	—			3.60		%	3.60		%	—

(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~~June 30, ~~2022~~2023 or December 31, ~~2021~~2022 and are reported within Other long-term debt in the Registrants’ respective Condensed Consolidated Balance Sheets when applicable.

5551

As of ~~September~~June 30, ~~2022,~~2023, finance lease liabilities were not significant to the Registrants. As of ~~September~~June 30, ~~2022,~~2023, maturities of operating lease liabilities were as follows:


		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC
		(in millions)							(in millions)
Remainder of 2022		$	2	$	—	$	1
2023		5		—		2
Remainder of 2023								Remainder of 2023	$	3	$	—	$	1
2024	2024	4		—		2		2024	4		2		2
2025	2025	2		—		1		2025	3		2		1
2026	2026	2		—		1		2026	3		2		1
2027 and beyond		2		—		—
2027								2027	2		1		—
2028								2028	2		—		—
2029 and beyond								2029 and beyond	1		—		—
Total lease payments	Total lease payments	17		—		7		Total lease payments	18		7		5
Less: Interest	Less: Interest	2		—		1		Less: Interest	2		1		—
Present value of lease liabilities	Present value of lease liabilities	$	15	$	—	$	6	Present value of lease liabilities	$	16	$	6	$	5

As of ~~September~~June 30, ~~2022,~~2023, 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.~~Registrants. As of ~~September~~June 30, ~~2022,~~2023, maturities of undiscounted operating lease payments to be received are as follows:


		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC
		(in millions)							(in millions)
Remainder of 2022		$	1	$	—	$	1
2023		7		1		4
Remainder of 2023								Remainder of 2023	$	3	$	—	$	2
2024	2024	7		1		4		2024	6		1		5
2025	2025	7		1		4		2025	8		1		5
2026	2026	7		—		4		2026	8		—		5
2027	2027	7		—		4		2027	8		—		5
2028 and beyond		160		—		156
2028								2028	7		—		5
2029 and beyond								2029 and beyond	176		—		170
Total lease payments to be received	Total lease payments to be received	$	196	$	3	$	177	Total lease payments to be received	$	216	$	2	$	197

Other information related to leases is as follows:


															Three Months Ended June 30, 2023						Three Months Ended June 30, 2022
															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														Operating cash flows from operating leases included in the measurement of lease liabilities	$	1	$	1	$	1	$	1	$	—	$	—

		Three Months Ended September 30, 2022						Three Months Ended September 30, 2021							Six Months Ended June 30, 2023						Six Months Ended June 30, 2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	Operating cash flows from operating leases included in the measurement of lease liabilities	$	1	$	—	$	—	$	2	$	—	$	1	Operating cash flows from operating leases included in the measurement of lease liabilities	$	3	$	1	$	1	$	3	$	—	$	1
Financing cash flows from finance leases included in the measurement of lease liabilities	Financing cash flows from finance leases included in the measurement of lease liabilities	47		47		—		—		—		—		Financing cash flows from finance leases included in the measurement of lease liabilities	—		—		—		171		171		—

		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.

5652

(20) Subsequent Events (CenterPoint Energy)

On July 19, 2023, CenterPoint Energy’s Board of Directors declared the following cash dividends to shareholders of record as of the close of business on the applicable record dates.

Equity Instrument

Declaration Date

Record Date

Payment Date

Per Share

Common Stock

July 19, 2023

August 17, 2023

September 14, 2023

0.1900

Series A Preferred Stock

July 19, 2023

August 15, 2023

September 1, 2023

30.6250

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~~2022 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

Divestiture of Energy Systems Group.On May 21, 2023, Vectren Energy Services entered into an Equity Purchase Agreement to sell all of the outstanding limited liability company interests of Energy Systems Group to ESG Holdings Group, for a purchase price of $157 million, subject to customary adjustments set forth in the Equity Purchase Agreement, including adjustments based on Energy Systems Group’s net working capital at closing, indebtedness, cash and cash equivalents and transaction expenses. The transaction closed on June 30, 2023 for $154 million in cash, subject to finalization of the purchase price adjustment. For further information, see Note 3 to the Interim Condensed Financial Statements.

Regulatory Proceedings. ~~The commissioners of~~On March 23, 2023, CenterPoint Energy and CERC, collectively, received approximately $1.1 billion in proceeds from the ~~MPUC held deliberations in August 2022 regarding CERC’s natural gas cost prudency review case~~customer rate relief bonds issued by the Texas Public Financing Authority related to the February 2021 Winter Storm Event. AsOn April 5, 2023, a ~~result,~~final order was issued approving the ~~MPUC disallowed~~$39 million revenue requirement from Houston Electric’s 2021 investment in TEEEF. On April 5, 2023, Houston Electric filed its second TEEEF filing requesting recovery of ~~approximately $36~~$188 million of ~~jurisdictional gas~~TEEEF related costs incurred ~~during~~through December 31, 2022. On June 29, 2023, Indiana Electric received the ~~event (or about 8.7%~~net securitization proceeds of $337 million to reimburse it for or fund qualified costs approved by the ~~total~~IURC related to the planned retirement of ~~such costs incurred by CERC) and CERC’s regulatory asset balance as of September 30, 2022 was reduced to reflect the disallowance.~~its A.B. Brown coal-fired generation facilities. 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,~~2023, see “—Liquidity and Capital Resources —Regulatory Matters” below.

Debt Transactions. During the ~~nine~~six months ended ~~September~~June 30, ~~2022, Houston Electric issued $1,600 million and CERC~~2023, CenterPoint Energy issued or borrowed ~~$1,000 million~~a combined $3.7 billion in new debt, ~~excluding the debt exchanges discussed below.~~including Houston Electric’s issuance of $900 million aggregate principal amount of general mortgage bonds, CERC’s issuance of $1.5 billion aggregate principal amount of senior notes, CERC’s $500 million term loan, Securitization Subsidiary’s issuance of $341 million aggregate principal amount of SIGECO Securitization Bonds, SIGECO’s issuance of $180 million aggregate principal amount of first mortgage bonds and CenterPoint Energy’s $250 million term loan. CenterPoint Energy repaid or redeemed a combined ~~$1,330 million~~$2.54 billion of debt, including CERC’s repayment of $1.0 billion of term loans and $1.275 billion of senior notes maturing in 2023, CenterPoint Energy’s repayment of its $250 million term loan and SIGECO’s early redemption of ~~$425~~$11 million of ~~debt, but~~first mortgage bonds maturing in 2044, 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,~~2023, see Note 11 to the Interim Condensed Financial Statements.

~~Debt Exchange.~~CenterPoint Energy Leadership Transition. On ~~September 6, 2022, CERC Corp. and VUH~~March 15, 2023, CenterPoint Energy 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~~the appointment 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 11Christopher Foster to the ~~Interim Condensed~~position of Executive Vice President and Chief Financial ~~Statements.~~

~~As a part of the Restructuring, on~~Officer, effective 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.

5, 2023.

5754

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~~2022 Form ~~10-K and in Item 1A of Part II of this combined Form 10-Q.~~10-K.

Income available to common shareholders for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022 was as follows:


		Three Months Ended September 30,						Nine Months Ended September 30,							Three Months Ended June 30,						Six Months Ended June 30,
		2022		2021		Favorable (Unfavorable)		2022		2021		Favorable (Unfavorable)			2023		2022		Favorable (Unfavorable)		2023		2022		Favorable (Unfavorable)
		(in millions)													(in millions)
Electric	Electric	$	234	$	185	$	49	$	489	$	385	$	104	Electric	$	180	$	173	$	7	$	303	$	255	$	48
Natural Gas	Natural Gas	(10)		5		(15)		416		308		108		Natural Gas	35		28		7		269		426		(157)
Total Utility Operations	Total Utility Operations	224		190		34		905		693		212		Total Utility Operations	215		201		14		572		681		(109)
Corporate & Other (1)														Corporate & Other (1)	(109)		(22)		(87)		(153)		16		(169)

Corporate & Other (1)		(35)		(63)		28		(19)		(145)		126
Discontinued Operations		—		68		(68)		—		202		(202)
Total CenterPoint Energy	Total CenterPoint Energy	$	189	$	195	$	(6)	$	886	$	750	$	136	Total CenterPoint Energy	$	106	$	179	$	(73)	$	419	$	697	$	(278)

(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~~June 30, ~~2022~~2023 compared to three months ended ~~September~~June 30, ~~2021~~2022

Income available to common shareholders decreased $6$73 million primarily due to the following items:

•an increase in income available to common shareholders of $7 million for the Electric reportable segment, as further discussed below;

•an increase in income available to common shareholders of $7 million for the Natural Gas reportable segment, as further discussed below;

•a decrease in income available to common shareholders of $87 million for Corporate and Other, primarily due to a loss on sale of $12 million and current tax expense of $33 million related to the divestiture of Energy Systems Group further discussed in Note 3 to the Interim Condensed Financial Statements, as well as $19 million due to remeasurement of deferred income tax balances. The remaining variance is due largely to an approximately $20 million increase in borrowing costs due to higher interest rates.

Six months ended June 30, 2023 compared to six months ended June 30, 2022

Income available to common shareholders decreased $278 million primarily due to the following items:

•an increase in net income of ~~$49~~$48 million for the Electric reportable segment, as further discussed below;

•a decrease in net income of ~~$15~~$157 million for the Natural Gas reportable segment, as further discussed below;

•~~an increase~~a decrease 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~~$169 million for Corporate and Other, primarily due to ~~a $28 million~~the pre-tax ~~payment related to the impact of Board-implemented governance changes announced in July 2021, the~~ net gain of $86 million on the sale of Energy Transfer equity securities in 2022 further discussed ~~further~~ in Note 10 to the Interim Condensed Financial Statements, ~~and a decrease in income allocated to preferred shareholders of~~partially offset by $45 million ~~primarily due~~of costs associated with early redemption of long-term debt in first quarter 2022, a loss on sale of $12 million and current tax expense of $33 million related to the ~~conversion~~divestiture of ~~the Series B Preferred Stock to Common Stock during 2021; and~~

•~~a decrease in income of $202 million from discontinued operations,~~Energy Systems Group further discussed ~~further~~ in Note 3 to the Interim Condensed Financial ~~Statements.~~Statements, as well as $19 million due to remeasurement of deferred income tax balances. The remaining variance is due largely to an approximately $30 million increase in borrowing costs due to higher interest rates.

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

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 CenterPoint Energy’s results of operations ~~by reportable segment concentrates on CenterPoint Energy’s Utility Operations, conducted through~~is separated into two reportable segments, Electric and Natural Gas.

Electric (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of ~~the~~CenterPoint Energy’s Electric reportable segment, please read “Risk Factors — Risk Factors ~~Associated with Our Consolidated Financial Condition,~~Affecting Operations — Electric Generation, Transmission and Distribution,” “— Risk Factors Affecting ~~Electric Generation, Transmission~~Regulatory, Environmental and ~~Distribution Businesses,~~Legal Risks,” “— Risk Factors Affecting ~~Our Businesses”~~Financial, Economic and Market Risks,” “— Risk Factors Affecting Safety and Security Risks” and “— General ~~Risk Factors Affecting Our Businesses”~~and Other Risks” in Item 1A of Part I of the Registrants’ combined ~~2021~~2022 Form ~~10-K and in Item 1A of Part II of this combined Form 10-Q.~~10-K.

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 %


	Three Months Ended June 30,									Six Months Ended June 30,
	2023			2022			Favorable (Unfavorable)			2023			2022			Favorable (Unfavorable)
	(in millions, except operating statistics)
Revenues	$	1,037		$	1,053		$	(16)		$	1,989		$	1,946		$	43
Expenses:
Utility natural gas, fuel and purchased power	19			56			37			79			97			18
Operation and maintenance	450			449			(1)			876			886			10
Depreciation and amortization	218			205			(13)			409			397			(12)
Taxes other than income taxes	68			72			4			135			140			5

Total expenses	755			782			27			1,499			1,520			21
Operating Income	282			271			11			490			426			64
Other Income (Expense):
Interest expense and other finance charges	(71)			(59)			(12)			(132)			(116)			(16)

Other income, net	14			7			7			26			12			14
Income Before Income Taxes	225			219			6			384			322			62
Income tax expense	45			46			1			81			67			(14)
Net Income	$	180		$	173		$	7		$	303		$	255		$	48
Throughput (in GWh):
Residential	9,036			10,003			(10)		%	15,004			16,349			(8)		%
Total	28,009			29,270			(4)		%	49,765			52,425			(5)		%
Weather (percentage of 10-year average for service area):
Cooling degree days	105		%	126		%	(21)		%	109		%	118		%	(9)		%
Heating degree days	78		%	53		%	25		%	86		%	121		%	(35)		%
Number of metered customers at end of period:
Residential	2,561,331			2,517,362			2		%	2,561,331			2,517,362			2		%
Total	2,887,492			2,840,830			2		%	2,887,492			2,840,830			2		%

5956

The following table provides variance explanations for the three months ended June 30, 2023 compared to the three months ended June 30, 2022 as well as for the six months ended June 30, 2023 compared to the six months ended June 30, 2022 by major income statement caption for the Electric reportable segment:


		Favorable (Unfavorable)					Favorable (Unfavorable)
		Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021			Three Months Ended June 30, 2023 vs 2022		Six Months Ended June 30, 2023 vs 2022
		(in millions)					(in millions)
Revenues	Revenues					Revenues
Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers, partially offset in operation and maintenance		$	40	$	115
Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers, partially offset in operation and maintenance below						Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers, partially offset in operation and maintenance below	$	19	$	74
Customer rates						Customer rates	46		68
Cost of fuel and purchased power, offset in utility natural gas, fuel and purchased power below						Cost of fuel and purchased power, offset in utility natural gas, fuel and purchased power below	(37)		(18)
Customer growth						Customer growth	6		12

Miscellaneous revenues, including service connections and off-system sales						Miscellaneous revenues, including service connections and off-system sales	(7)		(9)
Bond Companies equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods						Bond Companies equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods	(2)		(4)
Energy efficiency, and other pass-through, offset in operation and maintenance below						Energy efficiency, and other pass-through, offset in operation and maintenance below	7		7
Weather, efficiency improvements and other usage impacts	Weather, efficiency improvements and other usage impacts	11		53		Weather, efficiency improvements and other usage impacts	(30)		(48)
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)
Bond Companies, offset in other line items below						Bond Companies, offset in other line items below	(18)		(39)
Total	Total	$	90	$	269	Total	$	(16)	$	43
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power					Utility natural gas, fuel and purchased power
Cost of fuel, including coal, natural gas, and fuel oil, offset in revenues above						Cost of fuel, including coal, natural gas, and fuel oil, offset in revenues above	$	6	$	7
Cost of purchased power, offset in revenues above	Cost of purchased power, offset in revenues above	$	9	$	16	Cost of purchased power, offset in revenues above	31		11
Cost of fuel, including coal, natural gas, and fuel oil, offset in revenues above		(21)		(36)
Total	Total	$	(12)	$	(20)	Total	$	37	$	18
Operation and maintenance	Operation and maintenance					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)
All other operation and maintenance expense, including materials and supplies and insurance						All other operation and maintenance expense, including materials and supplies and insurance	$	11	$	27
Energy efficiency, and other pass-through, offset in revenues above						Energy efficiency, and other pass-through, offset in revenues above	(7)		(7)
Labor and benefits						Labor and benefits	4		13
Contract services	Contract services	—		(8)		Contract services	(2)		(2)
Bond Companies, offset in other line items	Bond Companies, offset in other line items	1		2		Bond Companies, offset in other line items	1		1
Energy efficiency and pass-through offset in revenues, including NOx emission credits		(18)		(13)
Support services, primarily information technology cost						Support services, primarily information technology cost	(6)		(1)

Labor and benefits		6		6
Support services, primarily information technology cost		5		22

Transmission costs billed by transmission providers, offset in revenues above						Transmission costs billed by transmission providers, offset in revenues above	(2)		(21)
Total	Total	$	(25)	$	(71)	Total	$	(1)	$	10
Depreciation and amortization	Depreciation and amortization					Depreciation and amortization
Bond Companies, offset in other line items	Bond Companies, offset in other line items	$	21	$	10	Bond Companies, offset in other line items	$	13	$	31
Ongoing additions to plant-in-service	Ongoing additions to plant-in-service	(12)		(30)		Ongoing additions to plant-in-service	(26)		(43)
Total	Total	$	9	$	(20)	Total	$	(13)	$	(12)
Taxes other than income taxes	Taxes other than income taxes					Taxes other than income taxes

Franchise fees and other taxes	Franchise fees and other taxes	$	2	$	5	Franchise fees and other taxes	$	2	$	3
Incremental capital projects placed in service, net of updated property tax rates	Incremental capital projects placed in service, net of updated property tax rates	—		(7)		Incremental capital projects placed in service, net of updated property tax rates	2		2
Total	Total	$	2	$	(2)	Total	$	4	$	5
Interest expense and other finance charges	Interest expense and other finance charges					Interest expense and other finance charges
Changes in outstanding debt						Changes in outstanding debt	$	(19)	$	(35)
Bond Companies, offset in other line items	Bond Companies, offset in other line items	$	2	$	6	Bond Companies, offset in other line items	2		4
Incremental borrowings to fund capital expenditures and interest rates		(3)		(9)
Other, primarily AFUDC and impacts of regulatory deferrals						Other, primarily AFUDC and impacts of regulatory deferrals	5		15
Total	Total	$	(1)	$	(3)	Total	$	(12)	$	(16)
Other income, net	Other income, net					Other income, net
Other non-operating income		$	2	$	2
Other income, including AFUDC - Equity						Other income, including AFUDC - Equity	$	7	$	14

Total	Total	$	2	$	2	Total	$	7	$	14

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

6057

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,~~Affecting Operations — Natural Gas,” “— Risk Factors Affecting ~~Natural Gas' Business,~~Regulatory, Environmental and Legal Risks,” “— Risk Factors Affecting ~~Our Businesses”~~Financial, Economic and Market Risks,” “— Risk Factors Affecting Safety and Security Risks” and “— General ~~Risk Factors Affecting Our Businesses”~~and Other Risks” in Item 1A of Part I of the Registrants’ combined ~~2021~~2022 Form ~~10-K and in Item 1A of Part II of this combined Form 10-Q.~~10-K.

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


		Three Months Ended September 30,									Nine Months Ended September 30,										Three Months Ended June 30,									Six Months Ended June 30,
		2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)				2023			2022			Favorable (Unfavorable)			2023			2022			Favorable (Unfavorable)
		(in millions, except operating statistics)																			(in millions, except operating statistics)
Revenues	Revenues	$	692		$	619		$	73		$	3,334		$	3,022		$	312		Revenues	$	764		$	818		$	(54)		$	2,539		$	2,642		$	(103)
Expenses:	Expenses:																			Expenses:
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power	284			170			(114)			1,698			1,274			(424)			Utility natural gas, fuel and purchased power	261			357			96			1,279			1,414			135
Non-utility cost of revenues, including natural gas	Non-utility cost of revenues, including natural gas	1			3			2			3			15			12			Non-utility cost of revenues, including natural gas	—			1			1			1			2			1
Operation and maintenance	Operation and maintenance	199			225			26			654			715			61			Operation and maintenance	222			209			(13)			450			455			5
Depreciation and amortization	Depreciation and amortization	118			135			17			347			392			45			Depreciation and amortization	128			117			(11)			250			229			(21)
Taxes other than income taxes	Taxes other than income taxes	51			53			2			189			184			(5)			Taxes other than income taxes	59			61			2			129			138			9
Total expenses	Total expenses	653			586			(67)			2,891			2,580			(311)			Total expenses	670			745			75			2,109			2,238			129
Operating Income	Operating Income	39			33			6			443			442			1			Operating Income	94			73			21			430			404			26
Other Income (Expense):	Other Income (Expense):																			Other Income (Expense):
Gain on sale	Gain on sale	—			8			(8)			303			8			295			Gain on sale	—			—			—			—			303			(303)
Interest expense and other finance charges	Interest expense and other finance charges	(34)			(34)			—			(97)			(101)			4			Interest expense and other finance charges	(48)			(33)			(15)			(92)			(63)			(29)

Other income (expense), net	Other income (expense), net	—			(1)			1			(10)			1			(11)			Other income (expense), net	4			(10)			14			6			(10)			16
Income Before Income Taxes	Income Before Income Taxes	5			6			(1)			639			350			289			Income Before Income Taxes	50			30			20			344			634			(290)
Income tax expense	Income tax expense	15			1			(14)			223			42			(181)			Income tax expense	15			2			(13)			75			208			133
Net Income (Loss)	Net Income (Loss)	$	(10)		$	5		$	(15)		$	416		$	308		$	108		Net Income (Loss)	$	35		$	28		$	7		$	269		$	426		$	(157)

Throughput (in Bcf):	Throughput (in Bcf):																			Throughput (in Bcf):
Residential	Residential	15			17			(12)		%	166			175			(5)		%	Residential	28			28			—		%	124			151			(18)		%
Commercial and Industrial	Commercial and Industrial	81			79			3		%	307			312			(2)		%	Commercial and Industrial	91			90			1		%	224			226			(1)		%
Total	Total	96			96			—		%	473			487			(3)		%	Total	119			118			1		%	348			377			(8)		%
Weather (percentage of 10-year average for service area):	Weather (percentage of 10-year average for service area):																			Weather (percentage of 10-year average for service area):
Heating degree days	Heating degree days	85		%	39		%	46		%	108		%	99		%	9		%	Heating degree days	88		%	102		%	(14)		%	88		%	108		%	(20)		%
Number of metered customers at end of period:	Number of metered customers at end of period:																			Number of metered customers at end of period:
Residential	Residential	3,920,848			4,332,079			(9)		%	3,920,848			4,332,079			(9)		%	Residential	3,965,118			3,919,079			1		%	3,965,118			3,919,079			1		%
Commercial and Industrial	Commercial and Industrial	296,144			348,443			(15)		%	296,144			348,443			(15)		%	Commercial and Industrial	299,213			295,487			1		%	299,213			295,487			1		%
Total	Total	4,216,992			4,680,522			(10)		%	4,216,992			4,680,522			(10)		%	Total	4,264,331			4,214,566			1		%	4,264,331			4,214,566			1		%

6158


		Favorable (Unfavorable)					Favorable (Unfavorable)
		Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021			Three Months Ended June 30, 2023 vs 2022		Six Months Ended June 30, 2023 vs 2022
		(in millions)					(in millions)
Revenues	Revenues					Revenues
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale						Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	—	$	(38)
Weather and usage						Weather and usage	17		(7)
Cost of natural gas, offset in utility natural gas, fuel and purchased power below	Cost of natural gas, offset in utility natural gas, fuel and purchased power below	$	132	$	538	Cost of natural gas, offset in utility natural gas, fuel and purchased power below	(96)		(112)
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
Gross receipts tax, offset in taxes other than income taxes below						Gross receipts tax, offset in taxes other than income taxes below	(1)		(7)
Energy efficiency, offset in operation and maintenance below						Energy efficiency, offset in operation and maintenance below	(5)		(9)

Non-volumetric and miscellaneous revenue						Non-volumetric and miscellaneous revenue	3		4
Changes in non-utility revenues						Changes in non-utility revenues	5		8
Customer growth	Customer growth	5		10		Customer growth	4		12
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)
Pass-through revenues, offset in operation and maintenance below						Pass-through revenues, offset in operation and maintenance below	6		15
Customer rates and impact of the change in rate design						Customer rates and impact of the change in rate design	13		31
Total	Total	$	73	$	312	Total	$	(54)	$	(103)
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power					Utility natural gas, fuel and purchased power
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale						Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	—	$	23
Cost of natural gas, offset in revenues above	Cost of natural gas, offset in revenues above	$	(132)	$	(538)	Cost of natural gas, offset in revenues above	96		112
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale		18		114

Total	Total	$	(114)	$	(424)	Total	$	96	$	135
Non-utility costs of revenues, including natural gas	Non-utility costs of revenues, including natural gas					Non-utility costs of revenues, including natural gas
Other, primarily non-utility cost of revenues	Other, primarily non-utility cost of revenues	$	2	$	12	Other, primarily non-utility cost of revenues	$	1	$	1
Total	Total	$	2	$	12	Total	$	1	$	1
Operation and maintenance	Operation and maintenance					Operation and maintenance

Corporate support services						Corporate support services	$	(2)	$	7
Labor and benefits						Labor and benefits	(3)		3
Energy efficiency, offset in revenues above						Energy efficiency, offset in revenues above	5		9
Miscellaneous operations and maintenance expense, including bad debt expense						Miscellaneous operations and maintenance expense, including bad debt expense	(3)		1
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	32	$	93	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		3
Labor and benefits		10		7
Energy efficiency, offset in revenues		3		5
Contract services	Contract services	(5)		(5)		Contract services	(4)		(3)
Other operation and maintenance expenses, including material and supplies and bad debt		(14)		(39)
Pass-through expense, offset in revenues above						Pass-through expense, offset in revenues above	(6)		(15)
Total	Total	$	26	$	61	Total	$	(13)	$	5
Depreciation and amortization	Depreciation and amortization					Depreciation and amortization
Incremental capital projects placed in service						Incremental capital projects placed in service	$	(11)	$	(23)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	20	$	50	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		2
Lower depreciation rates in Indiana from recent rate order		5		15
Incremental capital projects placed in service		(8)		(20)

Total	Total	$	17	$	45	Total	$	(11)	$	(21)
Taxes other than income taxes	Taxes other than income taxes					Taxes other than income taxes
Gross receipts tax, offset in revenues		$	1	$	(13)
Incremental capital projects placed in service		(3)		(8)
Gross receipts tax, offset in revenues above						Gross receipts tax, offset in revenues above	$	1	$	7
Other, primarily property taxes						Other, primarily property taxes	1		1
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	4		16		Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		1

Total	Total	$	2	$	(5)	Total	$	2	$	9
Gain on sale	Gain on sale					Gain on sale
Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	(8)	$	295	Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	—	$	(303)
Total	Total	$	(8)	$	295	Total	$	—	$	(303)
Interest expense and other finance charges	Interest expense and other finance charges					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)
Changes in outstanding debt						Changes in outstanding debt	$	(18)	$	(47)
Other, primarily AFUDC and impacts of regulatory deferrals						Other, primarily AFUDC and impacts of regulatory deferrals	3		18
Total	Total	$	—	$	4	Total	$	(15)	$	(29)

Other income (expense), net	Other income (expense), net					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
AFUDC - Equity, primarily from increased capital spend						AFUDC - Equity, primarily from increased capital spend	$	3	$	5
Decrease to non-service benefit cost						Decrease to non-service benefit cost	12		10
Other						Other	(1)		1

Total	Total	$	1	$	(11)	Total	$	14	$	16

6259

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,~~Affecting Operations — Electric Generation, Transmission and Distribution,” “— Risk Factors Affecting ~~Electric Generation, Transmission~~Regulatory, Environmental and ~~Distribution Businesses,~~Legal Risks,” “— Risk Factors Affecting ~~Our Businesses”~~Financial, Economic and Market Risks,” “— Risk Factors Affecting Safety and Security Risks” and “— General ~~Risk Factors Affecting Our Businesses”~~and Other Risks” in Item 1A of Part I of the Registrants’ combined ~~2021~~2022 Form ~~10-K and in Item 1A of Part II of this combined Form 10-Q.~~10-K.


		Three Months Ended September 30,									Nine Months Ended September 30,										Three Months Ended June 30,									Six Months Ended June 30,
		2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)				2023			2022			Favorable (Unfavorable)			2023			2022			Favorable (Unfavorable)
		(in millions, except operating statistics)																			(in millions, except operating statistics)
Revenues:	Revenues:																			Revenues:
TDU	TDU	$	879		$	794		$	85		$	2,394		$	2,159		$	235		TDU	$	868		$	822		$	46		$	1,628		$	1,515		$	113
Bond Companies	Bond Companies	56			80			(24)			168			185			(17)			Bond Companies	41			59			(18)			73			112			(39)
Total revenues	Total revenues	935			874			61			2,562			2,344			218			Total revenues	909			881			28			1,701			1,627			74
Expenses:	Expenses:																			Expenses:
Operation and maintenance, excluding Bond Companies	Operation and maintenance, excluding Bond Companies	393			394			1			1,190			1,154			(36)			Operation and maintenance, excluding Bond Companies	399			403			4			779			797			18
Depreciation and amortization, excluding Bond Companies	Depreciation and amortization, excluding Bond Companies	123			108			(15)			357			320			(37)			Depreciation and amortization, excluding Bond Companies	147			120			(27)			276			234			(42)
Taxes other than income taxes	Taxes other than income taxes	65			64			(1)			196			192			(4)			Taxes other than income taxes	67			68			1			131			131			—
Bond Companies	Bond Companies	54			76			22			157			169			12			Bond Companies	41			54			13			71			103			32
Total expenses	Total expenses	635			642			7			1,900			1,835			(65)			Total expenses	654			645			(9)			1,257			1,265			8
Operating Income	Operating Income	300			232			68			662			509			153			Operating Income	255			236			19			444			362			82
Other Income (Expense)	Other Income (Expense)																			Other Income (Expense)
Interest expense and other finance charges	Interest expense and other finance charges	(50)			(46)			(4)			(148)			(138)			(10)			Interest expense and other finance charges	(63)			(50)			(13)			(116)			(98)			(18)
Interest expense on Securitization Bonds	Interest expense on Securitization Bonds	(3)			(5)			2			(11)			(16)			5			Interest expense on Securitization Bonds	(2)			(4)			2			(4)			(8)			4

Other income, net	Other income, net	5			4			1			13			12			1			Other income, net	10			4			6			17			8			9
Income Before Income Taxes	Income Before Income Taxes	252			185			67			516			367			149			Income Before Income Taxes	200			186			14			341			264			77
Income tax expense	Income tax expense	52			34			(18)			108			60			(48)			Income tax expense	42			39			(3)			75			56			(19)
Net Income	Net Income	$	200		$	151		$	49		$	408		$	307		$	101		Net Income	$	158		$	147		$	11		$	266		$	208		$	58
Throughput (in GWh):	Throughput (in GWh):																			Throughput (in GWh):
Residential	Residential	11,525			10,723			7		%	27,223			24,448			11		%	Residential	8,741			9,710			(10)		%	14,393			15,698			(8)		%
Total	Total	28,928			29,318			(1)		%	78,565			74,453			6		%	Total	26,788			27,704			(3)		%	47,438			49,638			(4)		%
Weather (percentage of 10-year average for service area):	Weather (percentage of 10-year average for service area):																			Weather (percentage of 10-year average for service area):
Cooling degree days	Cooling degree days	105		%	101		%	4		%	111		%	103		%	8		%	Cooling degree days	105		%	127		%	(22)		%	109		%	118		%	(9)		%
Heating degree days	Heating degree days	—		%	—		%	—		%	124		%	105		%	19		%	Heating degree days	69		%	13		%	56		%	87		%	124		%	(37)		%
Number of metered customers at end of period:	Number of metered customers at end of period:																			Number of metered customers at end of period:
Residential	Residential	2,392,107			2,345,920			2		%	2,392,107			2,345,920			2		%	Residential	2,428,904			2,382,145			2		%	2,428,904			2,382,145			2		%
Total	Total	2,696,366			2,646,955			2		%	2,696,366			2,646,955			2		%	Total	2,735,799			2,686,295			2		%	2,735,799			2,686,295			2		%

6360


		Favorable (Unfavorable)					Favorable (Unfavorable)
		Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021			Three Months Ended June 30, 2023 vs 2022		Six Months Ended June 30, 2023 vs 2022
		(in millions)					(in millions)
Revenues	Revenues					Revenues
Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers	Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers	$	41	$	116	Transmission Revenues, including TCOS and TCRF, inclusive of costs billed by transmission providers	$	19	$	74
Weather impacts and other usage		14		56
Refund of protected and unprotected EDIT, offset in income tax expense		11		28
Customer rates						Customer rates	50		66

Customer growth	Customer growth	8		21		Customer growth	6		12

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	Equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods	(1)		2		Equity return, related to the annual true-up of transition charges for amounts over or under collected in prior periods	(2)		(4)
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)

Weather impacts and other usage						Weather impacts and other usage	(29)		(37)

Energy efficiency, offset in operations and maintenance below						Energy efficiency, offset in operations and maintenance below	2		2
Bond Companies, offset in other line items below						Bond Companies, offset in other line items below	(18)		(39)

Total	Total	$	61	$	218	Total	$	28	$	74
Operation and maintenance, excluding Bond Companies	Operation and maintenance, excluding Bond Companies					Operation and maintenance, excluding Bond Companies
Transmission costs billed by transmission providers, offset in revenues		$	(18)	$	(61)
Materials and Supplies, including fuel		(4)		(7)
All other operation and maintenance expense, including materials and supplies and insurance						All other operation and maintenance expense, including materials and supplies and insurance	$	9	$	28
Labor and benefits						Labor and benefits	4		12
Support services, primarily information technology cost						Support services, primarily information technology cost	(4)		—
Contract services	Contract services	—		(6)		Contract services	(1)		1
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

Energy efficiency, offset in revenues above						Energy efficiency, offset in revenues above	(2)		(2)
Transmission costs billed by transmission providers, offset in revenues above						Transmission costs billed by transmission providers, offset in revenues above	(2)		(21)
Total	Total	$	1	$	(36)	Total	$	4	$	18
Depreciation and amortization, excluding Bond Companies	Depreciation and amortization, excluding Bond Companies					Depreciation and amortization, excluding Bond Companies
Ongoing additions to plant-in-service	Ongoing additions to plant-in-service	$	(15)	$	(37)	Ongoing additions to plant-in-service	$	(27)	$	(42)
Total	Total	$	(15)	$	(37)	Total	$	(27)	$	(42)
Taxes other than income taxes	Taxes other than income taxes					Taxes other than income taxes
Franchise fees and other taxes	Franchise fees and other taxes	$	(1)	$	3	Franchise fees and other taxes	$	1	$	—
Incremental capital projects placed in service, net of updated property tax rates		—		(7)

Total	Total	$	(1)	$	(4)	Total	$	1	$	—
Bond Companies expense	Bond Companies expense					Bond Companies expense
Operations and maintenance and depreciation expense, offset in other line items		$	22	$	12
		$	22	$	12
Operations and maintenance and depreciation expense, offset in revenues above						Operations and maintenance and depreciation expense, offset in revenues above	$	13	$	32
Total						Total	$	13	$	32
Interest expense and other finance charges	Interest expense and other finance charges					Interest expense and other finance charges
Incremental borrowings to fund capital expenditures and changes in interest rates		$	(4)	$	(10)
Changes in outstanding debt						Changes in outstanding debt	$	(16)	$	(29)
Other, primarily AFUDC, impacts of regulatory deferrals						Other, primarily AFUDC, impacts of regulatory deferrals	3		11
Total	Total	$	(4)	$	(10)	Total	$	(13)	$	(18)

Interest expense on Securitization Bonds	Interest expense on Securitization Bonds					Interest expense on Securitization Bonds
Lower outstanding principal balance, offset in other line items		$	2	$	5
Lower outstanding principal balance, offset in revenues above						Lower outstanding principal balance, offset in revenues above	$	2	$	4
Total	Total	$	2	$	5	Total	$	2	$	4
Other income, net	Other income, net					Other income, net
Other non-operating income		$	1	$	1
Other income, including AFUDC - Equity						Other income, including AFUDC - Equity	$	6	$	9

Total	Total	$	1	$	1	Total	$	6	$	9

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

6461

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 single 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,~~Affecting Operations — Natural Gas,” “— Risk Factors Affecting ~~Natural Gas’ Business,~~Regulatory, Environmental and Legal Risks,” “— Risk Factors Affecting ~~Our Businesses”~~Financial, Economic and Market Risks,” “— Risk Factors Affecting Safety and Security Risks” and “— General ~~Risk Factors Affecting Our Businesses”~~and Other Risks” in Item 1A of Part I of the Registrants’ combined ~~2021~~2022 Form ~~10-K and in Item 1A of Part II of this combined Form 10-Q.~~10-K.


		Three Months Ended September 30,									Nine Months Ended September 30,										Three Months Ended June 30,									Six Months Ended June 30,
		2022			2021			Favorable (Unfavorable)			2022			2021			Favorable (Unfavorable)				2023			2022			Favorable (Unfavorable)			2023			2022			Favorable (Unfavorable)
		(in millions, except operating statistics)																			(in millions, except operating statistics)
Revenues	Revenues	$	672		$	609		$	63		$	3,232		$	2,925		$	307		Revenues	$	745		$	796		$	(51)		$	2,462		$	2,560		$	(98)
Expenses:	Expenses:																			Expenses:
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power	276			173			(103)			1,660			1,230			(430)			Utility natural gas, fuel and purchased power	260			351			91			1,258			1,384			126
Non-utility cost of revenues, including natural gas	Non-utility cost of revenues, including natural gas	1			4			3			3			16			13			Non-utility cost of revenues, including natural gas	—			1			1			1			2			1
Operation and maintenance	Operation and maintenance	190			223			33			630			709			79			Operation and maintenance	211			202			(9)			429			440			11
Depreciation and amortization	Depreciation and amortization	113			127			14			333			363			30			Depreciation and amortization	122			113			(9)			240			220			(20)
Taxes other than income taxes	Taxes other than income taxes	50			53			3			185			182			(3)			Taxes other than income taxes	59			60			1			128			135			7
Total expenses	Total expenses	630			580			(50)			2,811			2,500			(311)			Total expenses	652			727			75			2,056			2,181			125
Operating Income	Operating Income	42			29			13			421			425			(4)			Operating Income	93			69			24			406			379			27
Other Income (Expense):	Other Income (Expense):																			Other Income (Expense):
Gain on sale	Gain on sale	—			11			(11)			557			11			546			Gain on sale	—			—			—			—			557			(557)
Interest expense and other finance charges	Interest expense and other finance charges	(32)			(32)			—			(91)			(96)			5			Interest expense and other finance charges	(45)			(30)			(15)			(87)			(59)			(28)

Other income (expense), net		—			(2)			2			(11)			—			(11)
Other income, net																				Other income, net	5			(11)			16			6			(11)			17
Income Before Income Taxes	Income Before Income Taxes	10			6			4			876			340			536			Income Before Income Taxes	53			28			25			325			866			(541)
Income tax expense	Income tax expense	17			1			(16)			220			40			(180)			Income tax expense	10			1			(9)			70			203			133

Net Income (Loss)		$	(7)		$	5		$	(12)		$	656		$	300		$	356
Net Income																				Net Income	$	43		$	27		$	16		$	255		$	663		$	(408)
Throughput (in Bcf):	Throughput (in Bcf):																			Throughput (in Bcf):
Residential	Residential	14			16			(13)		%	161			170			(5)		%	Residential	27			27			—		%	121			147			(18)		%
Commercial and Industrial	Commercial and Industrial	74			72			3		%	281			289			(3)		%	Commercial and Industrial	81			82			(1)		%	206			207			—		%
Total	Total	88			88			—		%	442			459			(4)		%	Total	108			109			(1)		%	327			354			(8)		%
Weather (percentage of 10-year average for service area):	Weather (percentage of 10-year average for service area):																			Weather (percentage of 10-year average for service area):
Heating degree days	Heating degree days	85		%	40		%	45		%	108		%	99		%	9		%	Heating degree days	88		%	102		%	(14)		%	89		%	109		%	(20)		%
Number of metered customers at end of period:	Number of metered customers at end of period:																			Number of metered customers at end of period:
Residential	Residential	3,817,553			4,229,228			(10)		%	3,817,553			4,229,228			(10)		%	Residential	3,861,596			3,815,625			1		%	3,861,596			3,815,625			1		%
Commercial and Industrial	Commercial and Industrial	285,576			330,795			(14)		%	285,576			330,795			(14)		%	Commercial and Industrial	288,662			284,914			1		%	288,662			284,914			1		%
Total	Total	4,103,129			4,560,023			(10)		%	4,103,129			4,560,023			(10)		%	Total	4,150,258			4,100,539			1		%	4,150,258			4,100,539			1		%

6562


		Favorable (Unfavorable)					Favorable (Unfavorable)
		Three Months Ended September 30, 2022 vs 2021		Nine Months Ended September 30, 2022 vs 2021			Three Months Ended June 30, 2023 vs 2022		Six Months Ended June 30, 2023 vs 2022
		(in millions)					(in millions)
Revenues	Revenues					Revenues
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale						Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	—	$	(38)
Weather and usage						Weather and usage	17		(7)
Cost of natural gas, offset in utility natural gas, fuel and purchased power below	Cost of natural gas, offset in utility natural gas, fuel and purchased power below	$	121	$	544	Cost of natural gas, offset in utility natural gas, fuel and purchased power below	(91)		(103)
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
Gross receipts tax, offset in taxes other than income taxes below						Gross receipts tax, offset in taxes other than income taxes below	(1)		(6)
Energy efficiency, offset in operation and maintenance below						Energy efficiency, offset in operation and maintenance below	(5)		(8)

Non-volumetric and miscellaneous revenue						Non-volumetric and miscellaneous revenue	3		3
Changes in non-utility revenues						Changes in non-utility revenues	5		8

Pass-through revenues, offset in operation and maintenance below						Pass-through revenues, offset in operation and maintenance below	4		10
Customer growth	Customer growth	5		10		Customer growth	4		12
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)
Customer rates and impact of the change in rate design						Customer rates and impact of the change in rate design	13		31
Total	Total	$	63	$	307	Total	$	(51)	$	(98)
Utility natural gas, fuel and purchased power	Utility natural gas, fuel and purchased power					Utility natural gas, fuel and purchased power
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale						Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	—	$	23
Cost of natural gas, offset in revenues above	Cost of natural gas, offset in revenues above	$	(121)	$	(544)	Cost of natural gas, offset in revenues above	91		103
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale		18		114

Total	Total	$	(103)	$	(430)	Total	$	91	$	126
Non-utility costs of revenues, including natural gas	Non-utility costs of revenues, including natural gas					Non-utility costs of revenues, including natural gas
Other, primarily non-utility cost of revenues	Other, primarily non-utility cost of revenues	$	3	$	13	Other, primarily non-utility cost of revenues	$	1	$	1
Total	Total	$	3	$	13	Total	$	1	$	1
Operation and maintenance	Operation and maintenance					Operation and maintenance
Corporate support services						Corporate support services	$	(2)	$	7
Labor and benefits						Labor and benefits	(3)		4
Energy efficiency, offset in revenues above						Energy efficiency, offset in revenues above	5		8
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	32	$	93	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		3
Labor and benefits		10		8
Energy efficiency, offset in revenues		1		(1)
Miscellaneous operations and maintenance expense, including bad debt expense						Miscellaneous operations and maintenance expense, including bad debt expense	(3)		(1)
Contract services	Contract services	(3)		(3)		Contract services	(2)		—
Other operating and maintenance expense, including materials and supplies and insurance		(7)		(18)
Pass-through expense, offset in revenues above						Pass-through expense, offset in revenues above	(4)		(10)

Total	Total	$	33	$	79	Total	$	(9)	$	11
Depreciation and amortization	Depreciation and amortization					Depreciation and amortization
Incremental capital projects placed in service						Incremental capital projects placed in service	$	(9)	$	(22)
Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	20	$	50	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		2
Indiana lower depreciation rates from recent rate order		2		12
Incremental capital projects placed in service		(8)		(32)

Total	Total	$	14	$	30	Total	$	(9)	$	(20)
Taxes other than income taxes	Taxes other than income taxes					Taxes other than income taxes
Gross receipts tax, offset in revenues above						Gross receipts tax, offset in revenues above	$	1	$	6

Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	$	4	$	16	Nine days in January 2022 for Arkansas and Oklahoma Natural Gas businesses due to sale	—		1
Incremental capital projects placed in service		(2)		(6)
Gross receipts tax, offset in revenues		1		(13)
Total	Total	$	3	$	(3)	Total	$	1	$	7
Gain on sale	Gain on sale					Gain on sale
Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	(11)	$	546	Net gain on sale of Arkansas and Oklahoma Natural Gas businesses	$	—	$	(557)
Total	Total	$	(11)	$	546	Total	$	—	$	(557)
Interest expense and other finance charges	Interest expense and other finance charges					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)
Changes in outstanding debt						Changes in outstanding debt	$	(18)	$	(46)
Other, primarily AFUDC and impacts of regulatory deferrals						Other, primarily AFUDC and impacts of regulatory deferrals	3		18
Total	Total	$	—	$	5	Total	$	(15)	$	(28)

Other income (expense), net	Other income (expense), net					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
AFUDC - Equity, primarily from increased capital spend						AFUDC - Equity, primarily from increased capital spend	$	3	$	4
Decrease to non-service benefit cost						Decrease to non-service benefit cost	12		10
Other						Other	1		3

Total	Total	$	2	$	(11)	Total	$	16	$	17

6663

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~~2022 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~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021:~~2022:


		Nine Months Ended September 30,													Six Months Ended June 30,
		2022						2021							2023						2022
		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
		(in millions)													(in millions)
Cash provided by (used in):	Cash provided by (used in):													Cash provided by (used in):
Operating activities	Operating activities	$	1,325	$	545	$	753	$	(517)	$	497	$	(1,359)	Operating activities	$	2,482	$	415	$	2,147	$	978	$	188	$	767
Investing activities	Investing activities	(229)		(2,053)		921		(2,104)		(1,104)		(847)		Investing activities	(2,154)		(1,198)		(1,233)		942		(1,391)		1,394
Financing activities	Financing activities	(1,220)		1,402		(1,688)		2,610		576		2,201		Financing activities	(187)		769		(913)		(1,597)		1,066		(2,173)

Operating Activities. The following items contributed to increased (decreased) net cash provided by operating activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021:~~2022:


		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC
		(in millions)							(in millions)
Changes in net income after adjusting for non-cash items	Changes in net income after adjusting for non-cash items	$	(374)	$	164	$	(44)	Changes in net income after adjusting for non-cash items	$	150	$	84	$	(10)
Changes in working capital	Changes in working capital	(563)		(245)		(207)		Changes in working capital	487		191		320
Change in net regulatory assets and liabilities (1)	Change in net regulatory assets and liabilities (1)	2,457		150		2,334		Change in net regulatory assets and liabilities (1)	909		(80)		1,062
Change in equity in earnings of unconsolidated affiliates (2)		258		—		—
Change in distributions from unconsolidated affiliates (2)		(116)		—		—

Lower pension contribution		53		—		—

Other	Other	127		(21)		29		Other	(42)		32		8
		$	1,842	$	48	$	2,112		$	1,504	$	227	$	1,380

(1)~~The~~This change ~~in net regulatory assets and liabilities~~is primarily related to the receipt of proceeds at CenterPoint Energy and CERC ~~is primarily due to~~from 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.Texas securitization program. For further ~~information,~~details, see Note 36 to the Interim Condensed Financial Statements.

Investing Activities. The following items contributed to (increased) decreased net cash used in investing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021:~~2022:


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

Capital expenditures	Capital expenditures	(931)		(619)		(361)		Capital expenditures	(379)		(45)		(119)
Net change in notes receivable from affiliated companies	Net change in notes receivable from affiliated companies	—		(360)		25		Net change in notes receivable from affiliated companies	—		272		(417)

Proceeds from divestitures	Proceeds from divestitures	2,053		—		2,053		Proceeds from divestitures	(1,930)		—		(2,075)

Other	Other	51		30		51		Other	(85)		(34)		(16)
		$	1,875	$	(949)	$	1,768		$	(3,096)	$	193	$	(2,627)

Financing Activities. The following items contributed to (increased) decreased net cash used in financing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021:~~2022:


		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC
		(in millions)							(in millions)
Net changes in commercial paper outstanding	Net changes in commercial paper outstanding	$	(2,216)	$	—	$	(662)	Net changes in commercial paper outstanding	$	306	$	—	$	(480)

Net changes in long-term debt outstanding, excluding commercial paper		(1,899)		589		(1,272)
Net changes in long-term debt and term loans outstanding, excluding commercial paper								Net changes in long-term debt and term loans outstanding, excluding commercial paper	957		141		(696)

Net changes in debt issuance costs	Net changes in debt issuance costs	12		(3)		(1)		Net changes in debt issuance costs	(11)		(1)		(5)
Net changes in short-term borrowings	Net changes in short-term borrowings	484		—		484		Net changes in short-term borrowings	29		—		29

Proceeds from government grants								Proceeds from government grants	—		—		—
Payment of obligation for finance lease	Payment of obligation for finance lease	(218)		(218)		—		Payment of obligation for finance lease	171		171		—
Increased payment of common stock dividends	Increased payment of common stock dividends	(50)		—		—		Increased payment of common stock dividends	(26)		—		—
Decreased payment of preferred stock dividends		58		—		—

Net change in notes payable from affiliated companies	Net change in notes payable from affiliated companies	—		(544)		(1,720)		Net change in notes payable from affiliated companies	—		(20)		1,517
Contribution from parent	Contribution from parent	—		1,143		125		Contribution from parent	—		(493)		375
Dividend to parent	Dividend to parent	—		(141)		(844)		Dividend to parent	—		(93)		520

Other	Other	(1)		—		1		Other	(16)		(2)		—
		$	(3,830)	$	826	$	(3,889)		$	1,410	$	(297)	$	1,260

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~~six months of ~~2022~~2023 include the following:


		CenterPoint Energy		Houston Electric		CERC			CenterPoint Energy		Houston Electric		CERC
		(in millions)							(in millions)
Estimated capital expenditures	Estimated capital expenditures	$	1,088	$	552	$	413	Estimated capital expenditures	$	1,391	$	618	$	620
Scheduled principal payments on Securitization Bonds	Scheduled principal payments on Securitization Bonds	76		76		—		Scheduled principal payments on Securitization Bonds	79		79		—
Maturing senior notes								Maturing senior notes	57		—		57
Minimum contributions to pension plans and other post-retirement plans	Minimum contributions to pension plans and other post-retirement plans	3		—		1		Minimum contributions to pension plans and other post-retirement plans	7		1		2
Finance lease for TEEEF		271		271		—

The Registrants expect that anticipated cash needs for the remaining ~~three~~six months of ~~2022~~2023 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

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 Securitization of Planned Generation Retirements (CenterPoint Energy)

For further information about the issuance of SIGECO Securitization Bonds, 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.BTAs

On February 23, 2021, Indiana Electric filed a CPCN with the IURC seeking approval to purchase the Posey Solar project. On October 27, 2021, the IURC issued an order approving the CPCN, authorizing Indiana Electric to purchase the Posey Solar project through a BTA to acquire its solar array assets for a fixed purchase price and approved recovery of costs via a levelized rate over the anticipated 35-year life. Due to community feedback and rising project costs caused by inflation and supply chain issues affecting the energy industry, Indiana Electric, along with Arevon, the developer, announced plans in January 2022 to downsize the Posey Solar project to 191 MW. Indiana Electric collaboratively agreed to the scope change, and on February 1, 2023, Indiana Electric entered into an amended and restated BTA that is contingent on further IURC review and approval. On February 7, 2023, Indiana Electric filed a CPCN with the IURC to approve the amended BTA. With the passage of the IRA, Indiana Electric can now pursue PTCs for solar projects. Indiana Electric has filed an updated CPCN with a request that project costs, net of PTCs, be recovered in rate base, through base rates or the CECA mechanism, depending on which provides more timely recovery. The Posey Solar project is expected to be placed in service in 2025.

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 was held on November 1, 2022. On January 11, 2023, the IURC issued an order approving the settlement agreement granting Indiana Electric to purchase and acquire the Pike County solar project through a BTA and approved the estimated cost. The IURC also designated the project as a clean energy project, approved the proposed levelized rate and associated ratemaking and accounting treatment. The project is expected to be placed in service by the first quarter of 2025.

On January 10, 2023, Indiana Electric filed a CPCN with the IURC to acquire a wind energy generating facility with installed capacity of 200 MWs through a BTA, consistent with its 2019/2020 IRP that calls for up to 300 MWs of wind generation. The wind project is located in MISO’s Central Region zone 4. Commercial operation is expected as early as the end of 2025; however, factors (such as MISO interconnection process timing) could delay the project into 2026. Indiana Electric has requested recovery via the CECA mechanism or through base rates in the next general rate case, depending on which provides more timely recovery. On June 6, 2023 the IURC issued an order approving the CPCN, and thereby authorizing Indiana Electric to purchase the wind generating facility. However, as of the date of the filing of this Form 10-Q, Indiana Electric has not entered into any definitive agreement relating to this wind energy generating facility, and it is not certain that a definitive agreement will be entered into at all.

PPAs

Indiana Electric also sought approval in February 2021 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~~In 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. Due to rising project costs caused by inflation and supply chain issues affecting the energy industry, Clenera LLC and Indiana Electric were compelled to renegotiate terms of the agreement to increase the PPA price.On January 17, 2023, Indiana Electric filed a request with the IURC to amend the previously approved PPA with certain modifications. Revised purchase power costs are requested to be recovered through the

fuel adjustment clause proceedings over the term of the amended PPA. The ~~Posey~~amended PPA was approved by the IURC in the second quarter of 2023. The Clenera LLC solar ~~project~~array 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 fourthsecond 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

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.~~PPA with Origis and a hearing was held on January 4, 2023. On February 22, 2023, the IURC issued an order authorizing Indiana Electric to (i) enter into the amended PPA with Origis; (ii) recover the cost of the amended PPA over its full term as proposed; and (iii) use the proposed ratemaking treatment. On January 17, 2023, Indiana Electric filed a request with the IURC to amend the previously approved PPA with Oriden with certain modifications. Revised purchase power costs are requested to be recovered through the fuel adjustment clause proceedings over the term of the amended PPA with Oriden. The amended PPA with Oriden was approved by the IURC in the second quarter of 2023. The Oriden solar array is expected to be placed in service byin the ~~end~~second quarter of ~~2023~~2025 and the Origis solar array is expected to be placed in service by the ~~end~~third quarter of 2024.

Natural Gas Combustion Turbines

On ~~July 5,~~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. On June 28, 2022, the IURC approved the CPCN. 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. Indiana Electric entered into an agreement with Texas Gas Transmission, pending FERC approval of a ~~BTA~~necessary pipeline, to ~~acquire~~supply firm gas service to the new combustion turbines being constructed as part of the generation transition. On October 20, 2022, FERC granted Texas Gas Transmission a ~~130 MW solar array in Pike County,~~certificate to construct the pipeline. On November 21, 2022, the Citizens Action Coalition of Indiana, ~~through~~Inc. filed a ~~special purpose entity~~request for rehearing which was denied on June 8, 2023 when FERC issued a ~~capped purchase price. A CPCN~~Notice of Denial of Rehearing by Operation of Law. Separately, on February 21, 2023, Citizens Action Coalition of Indiana, Inc. filed a Petition for Review at the United States Court of Appeals for the ~~project was filed~~District of Columbia. The appeal is pending with the ~~IURC~~briefing schedule recently being released. Finally, on July ~~29, 2022. On September 21, 2022, an agreement~~7, 2023, FERC issued a Notice to Proceed with Full Construction and Modification Approvals, granting Texas Gas Transmission’s request to proceed, in ~~principle was reached resolving all~~full, with construction of the ~~issues between~~Henderson County Expansion Project. Indiana Electric ~~and OUCC.~~granted its contractor a full notice to proceed to construct the turbines on December 9, 2022. The ~~Stipulation and Settlement agreement was filed on October 6, 2022 and a settlement hearing~~facility is ~~scheduled for November 1, 2022. Pending approval, the project is expected~~targeted to be ~~placed~~operational by mid-2025. Recovery of the proposed natural gas combustion turbines and regulatory asset will be requested 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.~~the next Indiana Electric rate case expected in 2023.

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.~~turbine. 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 returnunit returned 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 earlyMarch 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~~Space City Solar Transmission Interconnection Project (CenterPoint Energy and Houston Electric)

On December 17, 2020, Houston Electric filed a certificate of convenience and necessity application with the PUCT for approval to build a 345 kV transmission line in Wharton County, Texas connecting the Hillje substation on Houston Electric’s transmission system to the planned 610 MW Space City Solar Generation facility being developed by third-party developer EDF Renewables. The actual capital costs of the project will depend on actual land acquisition costs, construction costs, and other factors. In November 2021, the PUCT approved a route that was estimated to cost $25 million and issued a final order on

January 12, 2022. There have been project delays due to supply chain constraints in the developer acquiring solar panels. Houston Electric expects to complete construction and the transmission line will be ready to be energized by the end of 2023.

Texas Legislation (CenterPoint Energy, Houston Electric and CERC)

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.~~2021. For example, ~~as a result of~~pursuant to legislation passed in 2021, Houston Electric entered into two leases for TEEEF (mobile generation) ~~which are detailed in Note 19 to~~. Additionally, the ~~Interim Condensed Financial Statements.~~2021 legislation allows Houston Electric ~~filed its DCRF application~~to seek recovery of transmission and distribution facilities that have a lead time of at least six months and would aid in restoring power to Houston Electric’s distribution customers following certain widespread power outages.Houston Electric plans to seek recovery of costs associated with ~~the PUCT on April 5, 2022, and subsequently amended such filing on July 1, 2022 to show mobile generation~~LLTF 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. 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.future DCRF or ratemaking proceeding. 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~~CERC are also reviewing legislation passed in ~~a customer outreach strategy, initially with~~2023, including the following pieces of legislation that became law during 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.88th Texas Legislature, including:

~~Minnesota Base Rate Cases (CenterPoint Energy~~•House Bill 1500 is effective September 1, 2023 and ~~CERC)~~

~~On November 1, 2021, CERC filed a general rate case with~~continues 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, extensionfunctions 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 toPUCT, the Office of ~~Administrative Hearings for~~Public Utility Counsel, and ERCOT through 2029. This bill also includes an amendment that clarifies the use cases under which TDUs may lease and operate temporary generation during “significant” power outages;

•House Bill 2263 is effective June 12, 2023 and authorizes local distribution companies to offer programs to promote energy conservation and to recover costs prudently incurred to implement such programs under Railroad Commission authority;

•House Bill 2555 is effective June 13, 2023 and allows an electric utility to create a ~~contested case proceeding. On March 14, 2022, an Offer of Settlement was filed~~transmission and distribution system resiliency plan with the ~~Office~~PUCT and associated cost recovery to enhance its system through hardening, undergrounding certain lines, flood mitigation measures, and vegetation management. We anticipate that the PUCT will open a rule making proceeding; the PUCT has until December 10, 2023 to adopt a rule;

•Senate Bill 947 is effective September 1, 2023 and creates severe criminal offenses for intentional damage to critical infrastructure facilities that create extended power outages;

•Senate Bill 1015 is effective June 18, 2023 and allows utilities to file the DCRF twice a year, on any day the PUCT is open (at least 185 days after filing a full base rate proceeding) and setting an administrative approval timeline of ~~Administrative Hearings which would resolve~~60 days;

•Senate Bill 1016 is effective May 5, 2023 and requires the PUCT to presume that all ~~issues in~~employee compensation and benefits are reasonable and necessary when establishing a utility’s rates if based upon market compensation studies issued within the ~~rate case. The settlement provides~~last three years; it includes exceptions for ~~a general revenue increase~~utility officer incentives that are based on financial metrics. Certain incentive compensation that is in-line with market studies will be presumed reasonable and recoverable; and

•Senate Bill 1076 is effective June 2, 2023 and moves the timeline for the PUCT to approve certificates of ~~$48.5 million~~convenience and ~~overall rate~~necessity for transmission projects to 180 days after the date of ~~return~~filing, rather than the first anniversary of ~~6.65%. On August 18, 2022,~~ the ~~MPUC orally approved the settlement, and a written order~~day it was ~~issued on September 23, 2022. After approval of CERC’s compliance filing, rate implementation is expected by January 1, 2023.~~filed.

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. 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. 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).

On June 28, 2023, CERC ~~expects to submit~~submitted its first innovation plan to the MPUC; the five-year plan includes 18 pilot projects and seven smaller research-and-development projects. These projects will deploy and evaluate a broad array of innovative resources including made-in-Minnesota alternative gases such as renewable natural gas and green hydrogen as well as pioneering technologies such as a networked geothermal district energy system and end-use carbon capture. The proposed plan requires approval from the MPUC inthrough a review process that is expected to take about one year. The MPUC has asked for comments by September 15, 2023 if parties believe that the ~~first half~~filing is incomplete based on the reporting requirements or if parties do not

Table of ~~2023.~~Contents

believe that that the MPUC’s standard informal proceeding process is appropriate. The ~~maximum allowable cost for an innovation plan will start at 1.75%~~initial comment period closes November 3, 2023, reply comments are due January 12, 2024 and supplemental comments are due February 2, 2024; the MPUC has indicated that unless warranted by comments received by September 15, 2023, it does not intend to hear this matter before the completion of the ~~utility's revenue in the state and could increase to 4% by 2033, subject to review and approval by the MPUC.~~entire comment period.

Solar Panel Issues (CenterPoint Energy)

CenterPoint Energy’s current and future solar projects ~~may be significantly~~have been 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~~On December 2, 2022, the DOC issued its preliminary determination, finding four of the eight companies being investigated are attempting to bypass U.S. duties; however, the investigation ~~including potential tariff amounts, are expected to be released in November 2022, with a~~continues and the DOC’s final ~~decision~~determination is now expected in ~~the first half of~~August 2023. In June

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 and legislative 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~~These impacts ~~result~~have resulted in cost increases for certain projects, and may result in cost increases in other projects, and such ~~potential~~ impacts have resulted in, or 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~~2022 Form ~~10-K and Item 1A of Part II of this combined Form 10-Q.~~10-K.

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~~Registrants are periodically involved in proceedings to adjust its capital tracking mechanisms ~~(TCOS~~(e.g., CSIA, DCRF, DRR, GRIP, 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)~~TDSIC), its cost of service adjustments ~~in Louisiana~~(e.g., RSP and ~~Mississippi (RSP and RRA, respectively)~~RRA), its decoupling mechanism ~~in Minnesota,~~(e.g., Decoupling 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)SRC), and its energy efficiency cost trackers ~~in Indiana (EEFC for gas~~(e.g., CIP, DSMA, EECR, EECRF, EEFC and ~~DSMA for electric) and Ohio (EEFR)~~EEFR). The table below reflects significant applications pending or completed since the Registrants’ combined ~~2021~~2022 Form 10-K was filed with the SEC through ~~October 28, 2022.~~the date of the filing of this Form 10-Q.

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~~DCRF (1)

2385

~~June~~April
~~2022~~2023

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~~approximately $1.9 billion for the period January 1, 2019 through December 31, ~~2021~~2022 for a revenue increase of ~~$86~~$85 million, adjusted for load growth. ~~In addition, the request includes approximately $200 million~~On July 14, 2023 a settlement was filed that results in ~~TEEEF during the calendar year ending December 31, 2021 representing~~ a revenue increase of ~~$57 million. The requested overall revenue increase is $142~~$70 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~~adjusted for ~~a black box reduction to the~~load growth.

TEEEF (1)

149

April
2023

TBD

A total Rider TEEEF revenue requirement of ~~$7.8~~$188 million for acost incurred through December 31, 2022. The revenue ~~increase of $78 million~~change between the rates resulting from the 2022 TEEEF and ~~a September 1, 2022 effective date for rates. A hearing on TEEEF issues was held on October 18 through 20, 2022.~~this application is $149 million.

TCOS

6440

~~February~~March 2023

May
2023

Based on net change in invested capital of $367 million for the period August 1, 2022 through January 31, 2023.

DCRF

117

April
2022

April ~~2022~~
2023

~~Based~~April 2023

A final order was issued on ~~net~~April 5, 2023 approving a TEEEF revenue requirement of $39 million with rates effective April 15, 2023. On April 28, 2023 and May 1, 2023 certain intervenors filed motions for rehearing of the PUCT’s April 5, 2023 order. On May 25, 2023 the PUCT issued its order on rehearing which clarified some of the findings, but did not change the approval of ~~invested capital~~TEEEF cost recovery. On June 19, 2023 certain intervenors filed motions for rehearing of ~~$574 million.~~the May 25, 2023 order on rehearing. The PUCT is expected to consider these motions at its August 3, 2023 open meeting. See Note 6 to the Interim Condensed Financial Statements for further information.

EECRF

June
2023

TBD

The requested $53 million is comprised primarily of the following: 2024 Program costs of $38 million; a credit of $2 million related to the over-recovery of 2022 program cost; the 2022 Earned bonus of $16 million and 2024 projected evaluation, measurement and verification costs of $1 million.

Mechanism

Annual Increase (Decrease) (1)

(in millions)

Filing
Date

Effective Date

Approval Date

Additional Information

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

GRIP

3460

March ~~2022~~2023

June
~~2022~~2023

Based on net change in invested capital for calendar year ~~2021~~2022 of ~~$213~~$390 million.

CenterPoint Energy and CERC - Minnesota (MPUC)

CIP Financial Incentive (1)

May
2023

TBD

CIP Financial Incentive based on 2022 CIP program activity.

CenterPoint Energy and CERC - Mississippi

RRA (1)

May
2023

TBD

Based ROE of 10.098% with 100 basis point (+/-) earnings band. Revenue increase of approximately $8 million based on 2022 test year adjusted earned ROE of 5.66%. Interim increase of approximately $1 million implemented May 31, 2023.

CenterPoint Energy and CERC - Louisiana (LPSC)

RSP ~~(1)~~

September 2022

~~TBD~~May
2023

~~TBD~~April 2023

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~~COVID-19 bad debt expenses in the amounts of $0.7 million and $0.3 million, respectively. Interim rates implemented on December 28, 2022, subject to refund. On April 5, 2023 the LPSC issued an order approving a joint settlement for $2.7 million in North Louisiana and $4.6 million in South Louisiana in addition to the full impacts of TCJA and COVID-19 recoveries. Implementation occurred in May 2023 upon approval of compliance tariff.

~~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~~April
2023

~~TBD~~July
2023

Requested an increase of ~~$12~~$33 million to rate base, which reflects approximately $1$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 ~~($1 million)~~$1 million annually. Also included are unrecovered deferred ~~O&M~~Operations & Management expenses of $9 million.
OUCC filed on June 2, 2023, recommending approval of the proposed CSIA rates and updated plan as filed, with non-cost recommendations. Rebuttal testimony filed June 16, 2023. A hearing was held June 28, 2023. The IURC issued an Order approving the CSIA on July 26, 2023.

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

CSIA (1)

179

~~October 2022~~April
2023

~~TBD~~July
2023

Requested an increase of ~~$38~~$95 million to rate base, which reflects ~~a $3~~approximately $9 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)~~$5 million annually. Also included isare unrecovered deferred O&M expenses of $20 million.
OUCC filed on June 2, 2023, recommending approval of the proposed CSIA rates and updated plan as filed, with non-cost recommendations. Rebuttal testimony was filed on June 16, 2023. A hearing was held June 28, 2023. The IURC issued an Order approving the CSIA on July 26, 2023.

CenterPoint Energy and CERC - Ohio (PUCO)

DRR (1)

5May
2023

April
2022TBD

~~September 2022~~

~~August 2022~~TBD

Requested an increase of ~~$63~~$46 million to rate base for investments made in ~~2021,~~2022, which reflects a $9$6 million annual increase in current revenues. A change in (over)/under-recovery variance of ~~$(4 million)~~$0.3 million annually is also included in rates. ~~Filed request on September~~PUCO staff review and recommendation filed June 29, 2023 recommending approval as proposed. VEDO statement of issues resolved in case filed July 14, ~~2022 to extend the DRR beyond 2023 for investment through December 31, 2026.~~2023.

Mechanism

Annual Increase (Decrease) (1)

(in millions)

Filing
Date

Effective Date

Approval Date

Additional Information

CenterPoint Energy - Indiana Electric (IURC)

TDSIC (1)

~~August 2022~~February 2023

~~TBD~~June
2023

~~TBD~~May
2023

Requested an increase of ~~$43~~$31 million to rate base, which reflects a $3$5 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 and a tax reform credit for a total of ~~less than~~ ($1 million). OUCC filed on April 3, 2023, recommending approval of the proposed TDSIC rates and updated plan as filed. A hearing was held on May 3, 2023. On May 30, 2023, the IURC issued an order approving the TDSIC rates an updated plan as filed with rates effective June 1, 2023.

~~ECA~~CECA (1)

—

6February 2023

June
2023

May ~~2022~~

~~August 2022~~

~~August 2022~~
2023

Requested an increase of ~~$21~~less than $1 million to rate base, which reflects ~~a $9 million~~an annual increase of less than $1 million 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). OUCC filed on March 31, 2023, recommending approval of the proposed CECA cost recovery with a reduction of approximately $0.3 million. Rebuttal testimony was filed on April 6, 2023. A hearing was held on May 3, ~~million).~~2023. On May 30, 2023, the IURC issued an order approving the CECA rates with a cost recovery reduction of approximately $0.3 million with rates effective June 6, 2023.

~~TDSIC~~ECA (1)

~~February 2022~~1

May
~~2022~~2023

May
2022TBD

TBD

Requested an increase of ~~$42~~$51 million to rate base, which reflects a $3$1 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~~DSMA (1)

~~(2)~~July
2023

~~February 2022~~TBD

June
2022TBD

May
2022

~~Requested a decrease~~The requested $45 million is comprised primarily of ~~less than $1~~the following: 2024 program costs of $11 million ~~to rate base, which reflects a~~and $26 million of lost revenue, $3 million ~~annual decrease in current revenues. The mechanism also includes a change in (over)/under-recovery variance~~related to the over-recovery of ~~less than $1 million. This mechanism includes a non-traditional rate making approach~~2022 program costs and $11 million under-recovery related to a ~~50 MW universal solar array placed in service in January 2021.~~

prior period variance adjustment; the requested $45 million is an increase of $16 million compared to the prior DSMA.

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

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, subject to certain exceptions, 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~~period (i.e., the CAMT). The IRA did not have a material impact on the Registrants’ 2022 financial results and no material impact is expected for 2023 financial results. The Registrants may be currently subject to the CAMT, pending future guidance relating to comments requested in response to Notice 2023-7. If the Registrants are subject to the CAMT for 2023, the calculation of regular tax will exceed minimum tax for 2023; therefore, no minimum tax is expected to be paid. Further guidance on the tax provisions of the IRA is expected and 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~~On May 10, 2023, the EPA ~~has announced it~~proposed regulations under Section 111 of the Clean Air Act which, if finalized, apply new GHG performance standards for those existing coal-fired units expected to continue operation beyond December 31, 2029. We are currently reviewing the proposal for applicability to existing and new gas-fired generating units, but would note that CenterPoint Energy does not currently have plans ~~on issuing new greenhouse gas rules in the future.~~to operate any of its coal-fired units beyond December 2029.

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 certain Scope 2 emissions by 2035 as well as a goal to reduce certain 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, in addition, exclude emissions related to purchased power in Indiana between 2024 and 2026 as estimated. CenterPoint Energy’s Scope 3 estimates are based on the total natural gas supply delivered to residential and commercial customers as reported in the U.S. Energy Information Administration (EIA) Form EIA-176 reports and 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~~proposed new regulations targeting reductions in methane emissions, which ~~are likely to~~if implemented will 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,TEEEF, 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.

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, legislators or ~~legislators~~other stakeholders could harm its reputation.

To address these developments, CenterPoint Energy announced its ~~new~~ net zero emissions goals for both Scope 1 and certain Scope 2 emissions by 2035. ~~In June of~~ Indiana Electric’s 2019/2020 ~~Indiana Electric~~IRP identified a preferred ~~generation resource in its most recent IRP submitted to the IURC~~portfolio that ~~aligns with its new net zero emissions goals and includes the replacement of~~retires 730 ~~MWs~~MW of coal-fired generation facilities and replaces these resources with a ~~significant portion comprised~~mix of generating resources composed primarily of renewables, including solar, wind, and ~~wind,~~solar with storage, supported by dispatchable natural gas combustion turbines including a pipeline to serve such natural gas ~~generation, as well as storage.~~generation. Indiana Electric continues to execute on its 2019/2020 IRP and has received initial approvals for 756 MWs of the 700-1,000 MWs identified within Indiana Electric’s 2019/2020 IRP. Additionally, as reflected in its 10-year capital plan announced in September 2021, CenterPoint Energy anticipates spending over $3 billion in ~~cleaner~~clean energy investments and enablement, which may be used to support, among other things, renewable energy 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. Indiana Electric has conducted a new IRP, which was submitted to the IURC in May 2023, to identify an appropriate generation resource portfolio to satisfy the needs of its customers and comply with environmental regulations. The proposed preferred portfolio is the second evolution to the generation transition plan to move away from coal-fired generation to a more sustainable portfolio of resources. Indiana Electric plans to convert its last remaining coal unit to natural gas by 2027 and to add a significant amount of additional renewable resources through 2033.

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,~~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~~current 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.its operation of TEEEF. 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

Table of ~~February 4, 2021. VUH did not incur any penalties in connection with the early termination.~~Contents

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~~$4.0 billion as of ~~September~~June 30, ~~2022.~~2023. As of ~~October 24, 2022,~~July 19, 2023, the Registrants had the following revolving credit facilities and utilization of such facilities:


				Amount Utilized as of October 24, 2022											Amount Utilized as of July 19, 2023
Registrant	Registrant	Size of Facility		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate	Termination Date	Registrant	Size of Facility		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate	Termination Date
		(in millions)											(in millions)
CenterPoint Energy	CenterPoint Energy	$	2,400	$	—	$	11	$	691	3.44%	February 4, 2024	CenterPoint Energy	$	2,400	$	—	$	8	$	1,564	5.44%	December 6, 2027

CenterPoint Energy (1)												CenterPoint Energy (1)	250		—		—		—		—%	December 6, 2027

Houston Electric	Houston Electric	300		—		—		—		—%	February 4, 2024	Houston Electric	300		—		—		—		—%	December 6, 2027
CERC	CERC	900		—		—		559		3.45%	February 4, 2024	CERC	1,050		—		1		—		—%	December 6, 2027
Total	Total	$	3,600	$	—	$	11	$	1,250			Total	$	4,000	$	—	$	9	$	1,564

(1)This credit facility was issued by SIGECO.

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~~SOFR 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~~SOFR 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~~four revolving credit facilities.

~~Long-term~~ Debt Transactions

For detailed information about the Registrants’ debt transactions to date in ~~2022,~~2023, see Note 11 to the Interim Condensed Financial Statements.

Securities Registered with the SEC

On May ~~29, 2020,~~17, 2023, 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.~~17, 2026. For information related to the Registrants’ debt issuances in ~~2022,~~2023, see Note 11 to the Interim Condensed Financial Statements.

Temporary Investments

As of ~~October 24, 2022,~~July 19, 2023, 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:~~July 19, 2023:

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


	Weighted Average Interest Rate	Houston Electric		CERC
		(in millions)
Money pool investments	5.49%	$	(183)	$	327

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,~~July 19, 2023, 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

CERC

Indiana Gas Senior Unsecured Debt

n/a

BBB+

Stable

n/a

(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~~June 30, ~~2022,~~2023, 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.

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~~up to $249 million as of ~~September~~June 30, ~~2022.~~2023. 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~~June 30, ~~2022,~~2023, deferred taxes of approximately ~~$659~~$697 million would have been payable in ~~2022.~~2023. If all the ZENS-Related Securities had been sold on ~~September~~June 30, ~~2022,~~2023, capital gains taxes of approximately ~~$68~~$76 million would have been payable in ~~2022~~2023 based on ~~2022~~2023 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 and CERC’s term loan agreement, a payment default on, or a non-payment default, event or condition 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. Under SIGECO’s revolving credit facility, a payment default on, or a non-payment default, event or condition that permits acceleration of, any indebtedness for borrowed money and certain other specific types of obligations (including guarantees) exceeding $75 million by SIGECO or any of its significant subsidiaries will cause a default under SIGECO’s credit facility. 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~~most recently increased its planned capital expenditures in its Electric and Natural Gas businesses in July 2023 to support further rate base ~~growth and~~growth. The Registrants may continue to 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~~its increased capital ~~expenditures.~~expenditures in the future, subject to the conditions listed above. 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. As of June 30, 2023, the total notional amount of CenterPoint Energy’s forward interest rate agreements was $75 million. 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

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, including weather hedging arrangements, 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~~financings on capital and ~~inflation rates;~~other financial markets;

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

•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;~~Electric;

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

•the satisfaction of any obligations pursuant to guarantees;

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

•contributions to pension and postretirement benefit plans;

•disruptions in the banking industry, including bank failures and uncertainty regarding bank stability;

•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~~2022 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

Certain provisions in certain note purchase agreements relating to debt issued by CERC have the effect of restricting the amount of secured debt issued by CERC and debt issued by subsidiaries of CERC Corp. Additionally, Houston Electric and SIGECO are limited in the amount of mortgage bonds they can issue by the General Mortgage and SIGECO’s mortgage indenture, respectively. For information about the total debt to capitalization financial covenants in the Registrants’ and ~~certain of CenterPoint Energy’s subsidiaries’~~SIGECO’s 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,~~goodwill, whenever events or changes in circumstances indicate that such carrying values may

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,~~goodwill, future cash flows, interest rate, and regulatory matters, and 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.~~unit as of the last annual test.

~~Although no~~From time to time, the Registrants consider the acquisition or the disposition of assets or businesses, and market information obtained through these exploratory activities is considered during the preparation of the financial statements to determine if an interim impairment test is required. The Registrants did not identify triggering events in connection with their preparation of the financial statements for the three months ended June 30, 2023, and goodwill impairment ~~resulted~~of long-lived asset impairments tests were not required or performed. See discussion below for goodwill attributable to disposed businesses, including assets held for sale.

Divestitures, including assets held for sale

Generally, a long-lived asset to be sold is classified as held for sale in the period in which management, with approval from the ~~2022 annual test, an interim goodwill impairment test could~~Board of Directors, as applicable, commits to a plan to sell, and a sale is expected to be ~~triggered by~~completed within one year. The Registrants record assets and liabilities held for sale, or the ~~following: actual earnings results that are materially~~disposal group, at the 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 bookof their carrying value ~~for an extended period~~or their estimated fair value less cost to sell. If a disposal group reflects a component 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 meetmeets the definition of a business, the ~~receiving entity will record an allocation of~~ goodwill ~~from the~~within that reporting unit is allocated to the disposal group based on the relative fair value of the ~~businesses transferred within~~components representing a business that will be retained and disposed. Goodwill is not allocated to a portion of a reporting ~~unit.~~unit that does not meet the definition of a business.

During the three and six months ended June 30, 2023, as described further in Note 3 to the Interim Condensed Financial Statements, certain assets and liabilities of Energy Systems Group representing a business were disposed. As a result of the held for sale criteria being met during the same period as the completion of the sale, goodwill attributable to Energy Systems Group of $134 million was reflected in the pre-tax loss on sale of $12 million based on the actual sale proceeds received at closing during the three and six months ended 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.2023.

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~~amount 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~~For further information, see Note 3 to the Interim Condensed Financial Statements.

Accounting for Securitization of Planned Generation Retirements

Accounting guidance for rate regulated long-lived asset abandonment requires that the carrying value of an operating asset or an asset under construction is removed from property, plant and equipment when it becomes probable that the ~~businesses within~~asset will be abandoned. The Registrants recognize either a loss on abandonment or regulatory asset when they concluded it is probable the ~~Natural Gas reporting unit was~~cost will be recovered in future rates. The portion of property, plant and equipment that will remain used and useful until abandonment and recovered through depreciation expense in rates will continue to be classified as property, plant and equipment until the asset is abandoned. The Registrants evaluate if an adjustment to the estimated ~~based~~life of the asset and, accordingly, the rate of depreciation, is required to recover the asset while it is still providing service. Determining probability of abandonment or probability of recovery requires significant judgment on ~~a weighted combination~~the part of ~~income~~management and ~~market approaches, consistent~~includes, but is not limited to, consideration of testimony presented in regulatory hearings, proposed regulatory decisions, final regulatory orders and the strength or status of applications for rehearing or state court appeals.

In connection with the ~~methodology used~~securitization financing of qualified costs in the ~~2021 annual goodwill impairment test.~~second quarter of 2023 associated with the planned retirement of SIGECO’s A.B. Brown coal generation facilities, CenterPoint Energy evaluated the VIE consisting of the Securitization Subsidiary, a wholly-owned, bankruptcy-remote, special purpose entity, for possible consolidation, including review of qualitative factors such as the power to direct the activities of the VIE and the obligation to absorb losses of the VIE. CenterPoint Energy has the power to direct the significant activities of the VIE and is most closely associated with the VIE as

compared to other interests held by the holders of the SIGECO Securitization Bonds. CenterPoint Energy is, therefore, considered the primary beneficiary and consolidated the VIE.

For purposes of reporting cash flows, the Registrants consider cash equivalents to be short-term, highly-liquid investments with maturities of three months or less from the date of purchase. Cash and cash equivalents held by the Securitization Subsidiary solely to support servicing the SIGECO Securitization Bonds as of June 30, 2023 are reflected on CenterPoint Energy’s Consolidated Balance Sheet.

In connection with the issuance of the SIGECO Securitization Bonds, CenterPoint Energy was required to establish a restricted cash account to collateralize the SIGECO Securitization Bonds that were issued in the financing transaction. The restricted cash account is not available for withdrawal until the maturity of the SIGECO Securitization Bonds and is not included in cash and cash equivalents.

For further information, see Notes 1 and 6 to the Interim Condensed Financial Statements.

Other than the ~~annual~~interim goodwill impairment ~~test~~review and ~~the common control~~securitization transaction discussed above, there have been no significant changes in our critical accounting policies during the ~~three and nine~~six months ended ~~September~~June 30, ~~2022,~~2023, 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~~2022 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.

Interest Rate Risk (CenterPoint Energy)

As of ~~September~~June 30, ~~2022,~~2023, 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~~$2.4 billion and $4.5 billion as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively. If the floating interest rates were to increase by ~~10%~~100 basis points from ~~September~~June 30, ~~2022~~2023 rates, CenterPoint Energy’s combined interest expense would increase by approximately $8$24 million annually. In April 2023, SIGECO executed a remarketing agreement to remarket five series of tax-exempt debt of approximately $148 million, which closed on May 1, 2023. SIGECO expects to remarket an additional $38 million of tax-exempt debt at then market rates due to mandatory purchase or mandatory tender for purchase provisions by the end of 2023. For further information, see Note 11 to the Interim Condensed Financial Statements. On September 1, 2023, CenterPoint Energy’s Series A Preferred Stock will convert from a fixed rate dividend rate to a floating rate per annum equal to three month U.S. dollar LIBOR (or alternative benchmark rate) plus 3.270%.

As of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, CenterPoint Energy had outstanding fixed-rate debt (excluding indexed debt securities) aggregating ~~$12.7~~$14.7 billion and ~~$11.7~~$12.5 billion, respectively, in principal amount and having a fair value of ~~$11.2~~$13.5 billion and ~~$13.0~~$11.1 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~~$634 million if interest rates were to decline by 10% from levels at ~~September~~June 30, ~~2022.~~2023. 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~~ On an ~~increase in fair value would impact earnings and cash flows only if~~unconsolidated basis, CenterPoint Energy ~~were~~has no fixed-rate senior notes maturing in 2023; however, CERC has $57 million of fixed-rate senior notes maturing in 2023 that it expects to ~~reacquire all or a portion of these instruments in the open market prior to their maturity.~~refinance at current rates.

The ZENS obligation is bifurcated into a debt component and a derivative component. The debt component of $8$6 million as of ~~September~~June 30, ~~2022~~2023 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~~June 30, ~~2022.~~2023. Changes in the fair value of the derivative component, a ~~$522~~$583 million recorded liability at ~~September~~June 30, ~~2022,~~2023, 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~~June 30, ~~2022~~2023 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~~June 30, ~~2022~~2023 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~~June 30, ~~2022,~~2023, the recorded fair value of non-trading energy derivative assets was ~~$34~~$1 million and ~~$27~~$1 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.

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~~June 30, ~~2022~~2023 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~~June 30, ~~2022~~2023 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, including environmental legal proceedings that involve a governmental authority as a party and that the Registrants reasonably believe would result in $1,000,000 or more of monetary sanctions, exclusive of interest and costs, under federal, state and local laws that have been enacted or adopted regulating the discharge of materials into the environment or primarily for the purpose of protecting the environment, affecting the Registrants, please read Note ~~13(d)~~13(c) 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

The collective bargaining agreement with IBEW 66 related to Houston Electric employees was scheduled to expire in May 2023. Houston Electric and IBEW 66 have agreed to renew the agreement on a monthly basis while active negotiations continue on a new collective bargaining agreement.

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~~2022 Form 10-K.

Item 1A.RISK FACTORS

~~Except for the updates below, there~~There have been no material changes from the risk factors disclosed in the Registrants’ combined ~~2021~~2022 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.~~Rule 10b5-1 Trading Arrangements

During the three months ended June 30, 2023, no director or officer of CenterPoint Energy, Houston Electric or CERC adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408 of Regulation S-K.

IBEW 66 Negotiations

~~Table~~

Entry into a Material Definitive Agreement

On July 26, 2023, CenterPoint Energy, JPMorgan Chase Bank, N.A., as administrative agent, and the banks party thereto entered into the First Amendment, amending the Credit Agreement. The First Amendment amends the Credit Agreement to clarify the events or conditions with respect to certain future indebtedness of ~~Contents~~CenterPoint Energy that may constitute an event of default under the Credit Agreement.

Certain banks party thereto may also participate in the revolving credit facilities of Houston Electric, CERC Corp. and SIGECO.

The First Amendment is filed as Exhibit 10.1 to this report and is incorporated by reference herein. The foregoing summary does not purport to be complete and is qualified in its entirety by reference to the First Amendment.

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 x
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 x
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 x x
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 x x
3.1
Restated Articles of Incorporation of CenterPoint Energy
CenterPoint Energy’s Form 8-K dated July 24, 2008 1-31447 3.2 x
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 x
3.3
Certificate of Incorporation of RERC Corp.

CERC Form 10-K for the year ended December 31, 1997 1-13265 3(a)(1) x
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) x
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) x
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) x
3.7
Third Amended and Restated Bylaws of CenterPoint Energy
CenterPoint Energy’s Form 8-K dated February 21, 2017 1-31447 3.1 x
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 x
3.9
Bylaws of RERC Corp.
CERC Form 10-K for the year ended December 31, 1997 1-13265 3(b) x
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) x

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

8381


Exhibit Number	Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC	Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
2.3*									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	x		x
2.4*									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	x		x
3.1									3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2	x
3.2									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		x
3.3									3.3	Certificate of Incorporation of RERC Corp.	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(a)(1)			x
3.4									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)			x
3.5									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)			x
3.6									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)			x
3.7									3.7	Third Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated February 21, 2017	1-31447	3.1	x
3.8									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		x
3.9									3.9	Bylaws of RERC Corp.	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(b)			x
3.10									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)	x
3.11	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			3.11	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	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			3.12	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	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			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	4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1	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	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			4.2	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	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		4.3	Indenture dated as of February 1, 1998, between CERC (formerly NorAm Energy Corp.) and The Bank of New York Mellon Trust Company, National Association (successor to 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
4.4		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

8482

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

Exhibit
Number

Description

Report or Registration
Statement

SEC File or
Registration
Number

Exhibit
Reference

CenterPoint Energy

Houston Electric

CERC

Exhibit
Number

Description

Report or Registration
Statement

SEC File or
Registration
Number

Exhibit
Reference

CenterPoint Energy

Houston Electric

CERC

4.10

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

4.4

Supplemental Indenture No. 23, dated as of February 23, 2023, to Exhibit 4.3

CERC’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2023

1-13265

4.6

†4.5

Supplemental Indenture No. 24, dated as of May 3, 2023, to Exhibit 4.3

†10.1

First Amendment to Second Amended and Restated Credit Agreement, dated as of July 26 , 2023

†31.1.1

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

†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

†31.1.2

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

†31.1.3

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

†31.1.3

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

†31.2.1

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

†31.2.1

Rule 13a-14(a)/15d-14(a) Certification of C hristopher A. Foster

†31.2.2

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

†31.2.2

Rule 13a-14(a)/15d-14(a) Certification of Christopher A. Foster

†31.2.3

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

†31.2.3

Rule 13a-14(a)/15d-14(a) Certification of Christopher A. Foster

†32.1.1

Section 1350 Certification of David J. Lesar

†32.1.1

Section 1350 Certification of David J. Lesar

†32.1.2

Section 1350 Certification of Scott E. Doyle

†32.1.2

Section 1350 Certification of Scott E. Doyle

†32.1.3

†32.1.3

†32.2.1

Section 1350 Certification of C hristopher A. Foster

†32.2.1

†32.2.2

Section 1350 Certification of Christopher A. Foster

†32.2.2

†32.2.3

Section 1350 Certification of Christopher A. Foster

†32.2.3

†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.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.SCH

Inline XBRL Taxonomy Extension Schema Document

†101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

†101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

†101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

†101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

†101.LAB

Inline XBRL Taxonomy Extension Labels Linkbase Document

†101.LAB

Inline XBRL Taxonomy Extension Labels Linkbase Document

†101.PRE

Inline XBRL Taxonomy Extension Presentation 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)

†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.

8583