0001130310-19-000041 | 10-Q | XBRL Viewer

Utility natural gas, fuel and purchased power

2,742

2,212

9,071

7,553

Expenses:

179

134

1,178

959

Non-utility cost of revenues, including natural gas

^[1]

852

864

3,013

2,927

Operation and maintenance

871

567

2,616

1,714

Taxes other than income taxes

334

326

987

982

114

353

307

2,350

1,986

8,147

6,889

Gain on marketable securities

392

226

924

664

Other Income (Expense):

206

Loss on indexed debt securities

(62)

(44)

(216)

(316)

Interest and other finance charges

(134)

(90)

(389)

(259)

Interest on Securitization Bonds

(9)

(16)

(31)

(46)

Equity in earnings of unconsolidated affiliates, net

213

208

Other income (expense), net

Income (Loss) Before Income Taxes

(60)

(17)

(177)

(331)

332

209

747

333

Income tax expense (benefit)

113

Net Income

270

158

634

248

Income Available to Common Shareholders

$ 241

$ 153

$ 546

$ 243

Basic Earnings Per Common Share

$ 0.48

$ 0.35

$ 1.09

$ 0.56

Diluted Earnings Per Common Share

$ 0.47

$ 0.35

$ 1.08

$ 0.56

Weighted Average Common Shares Outstanding, Basic

502,228,000

431,554,000

501,986,000

431,437,000

Weighted Average Common Shares Outstanding, Diluted

505,080,000

434,891,000

504,838,000

434,774,000

Revenues:

Operation and maintenance

$ 859

$ 897

$ 2,310

$ 2,506

Expenses:

359

369

1,086

1,062

Taxes other than income taxes

168

242

519

737

186

180

590

670

1,791

1,979

Interest and other finance charges

269

227

519

527

Other Income (Expense):

(41)

(32)

(123)

(101)

Interest on Securitization Bonds

(9)

(16)

(31)

(46)

Other income (expense), net

(6)

Income (Loss) Before Income Taxes

(43)

(48)

(137)

(153)

226

179

382

374

Income tax expense (benefit)

Net Income

185

143

312

296

Revenues:

Utility revenues

389

402

2,077

2,032

Non-utility revenues

737

910

2,759

3,008

Utility natural gas, fuel and purchased power

1,126

1,312

4,836

5,040

Expenses:

113

134

928

959

Non-utility cost of revenues, including natural gas

^[1]

687

864

2,627

2,927

Operation and maintenance

195

211

656

666

Taxes other than income taxes

228

222

120

1,103

1,319

4,559

4,894

Interest and other finance charges

(7)

277

146

Other Income (Expense):

(28)

(30)

(87)

(92)

Other income (expense), net

(3)

(6)

(5)

Income (Loss) Before Income Taxes

(31)

(30)

(93)

(97)

(8)

(37)

184

Income tax expense (benefit)

(1)

(2)

Income (Loss) From Continuing Operations

(7)

(35)

159

Income from discontinued operations (net of tax of $-0-, $13, $-0- and $44, respectively)

140

Net Income

$ (7)

$ 9

$ 159

$ 175

[1]	Income statement impact associated with cash flow hedge activity is related to gains and losses reclassified from Accumulated other comprehensive income into income. Amounts are immaterial for each Registrant in the three and nine months ended September 30, 2019 and 2018, respectively.

CONDENSED STATEMENTS OF CONSOLIDATED INCOME (Parentheticals) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
CERC Corp [Member]
Income tax expense associated with discontinued operations	$ 0	$ 13	$ 0	$ 44

Amount of tax expense (benefit) related to a discontinued operation. Includes, but is not limited to, tax expense (benefit) related to income (loss) from operations during the phase-out period, tax expense (benefit) related to gain (loss) on disposal, tax expense (benefit) related to gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and tax expense (benefit) related to adjustments of a prior period gain (loss) on disposal.

Organization, Consolidation and Presentation of Financial Statements [Abstract]

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income (Loss)	$ 270	$ 158	$ 634	$ 248
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans (net of tax of $-0-, $1, $2 and $2)	2	1	5	4
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $1, $-0- and $2)	(2)	3	(3)	6
Reclassification of deferred loss from cash flow hedges realized in net income (net of tax of $-0-, $-0-, $-0- and $-0-)	0	0	1	0
Other comprehensive loss from unconsolidated affiliates (net of tax of $-0-, $-0-, $-0- and $-0-)	(2)	0	(2)	0
Total	(2)	4	1	10
Comprehensive income	268	162	635	258
Houston Electric [Member]
Net income (Loss)	185	143	312	296
Other comprehensive income (loss):
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $1, $-0- and $2)	0	3	(1)	7
Total	0	3	(1)	7
Comprehensive income	185	146	311	303
CERC Corp [Member]
Net income (Loss)	(7)	9	159	175
Other comprehensive income (loss):
Total	0	0	0	0
Comprehensive income	$ (7)	$ 9	$ 159	$ 175

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Parentheticals) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Tax benefit (expense) on adjustment related to pension and postretirement plans	$ 0	$ (1)	$ (2)	$ (2)
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	0	(1)	0	(2)
Tax expense (benefit) on reclassification of deferred (gain) loss from cash flow hedges realized in net income	0	0	0	0
Tax benefit (expense) on Other comprehensive loss from unconsolidated affiliates	0	0	0	0
Houston Electric [Member]
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	$ 0	$ 1	$ 0	$ 2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 259	$ 4,231
Investment in marketable securities	746	540
Accounts receivable, less bad debt reserve	1,091	1,190
Accrued unbilled revenues	403	378
Natural gas inventory	299	194
Materials and supplies	273	200
Non-trading derivative assets	120	100
Taxes receivable	69	0
Prepaid expenses and other current assets	156	192
Total current assets	3,416	7,025
Property, Plant and Equipment:
Property, plant and equipment	30,066	20,267
Less: accumulated depreciation and amortization	9,738	6,223
Property, plant and equipment, net	20,328	14,044
Other Assets:
Goodwill	5,179	867
Regulatory assets	2,194	1,967
Non-trading derivative assets	64	38
Investment in unconsolidated affiliates	2,469	2,482
Preferred units – unconsolidated affiliate	363	363
Intangible assets, net	356	65
Other	273	158
Total other assets	10,898	5,940
Total Assets	34,642	27,009
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	229	458
Indexed debt, net	21	24
Current portion of other long-term debt	618	0
Indexed debt securities derivative	817	601
Accounts payable	888	1,240
Taxes accrued	193	204
Interest accrued	121	121
Dividends accrued	0	187
Customer deposits	122	86
Non-trading derivative liabilities	50	126
Other	375	255
Total current liabilities	3,434	3,302
Other Liabilities:
Deferred income taxes, net	3,851	3,239
Non-trading derivative liabilities	32	5
Benefit obligations	812	796
Regulatory liabilities	3,481	2,525
Other	672	402
Total other liabilities	8,848	6,967
Long-term Debt:
VIE Securitization Bonds, net	817	977
Other long-term debt, net	13,197	7,705
Total long-term debt, net	14,014	8,682
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized
Common stock	5	5
Additional paid-in capital	6,072	6,072
Retained earnings	636	349
Accumulated other comprehensive income (loss)	(107)	(108)
Total shareholders’ equity	8,346	8,058
Total Liabilities and Shareholders’ Equity	34,642	27,009
Houston Electric [Member]
Current Assets:
Cash and cash equivalents	228	335
Accounts and notes receivable, less bad debt reserve	341	283
Accounts and notes receivable–affiliated companies	787	20
Accrued unbilled revenues	136	110
Materials and supplies	144	135
Taxes receivable	0	5
Prepaid expenses and other current assets	30	61
Total current assets	1,666	949
Property, Plant and Equipment:
Property, plant and equipment	12,621	12,148
Less: accumulated depreciation and amortization	3,795	3,746
Property, plant and equipment, net	8,826	8,402
Other Assets:
Regulatory assets	951	1,124
Other	20	32
Total other assets	971	1,156
Total Assets	11,463	10,507
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	229	458
Accounts payable	232	262
Accounts and notes payable–affiliated companies	65	78
Taxes accrued	107	115
Interest accrued	44	64
Non-trading derivative liabilities	0	24
Other	69	89
Total current liabilities	746	1,090
Other Liabilities:
Deferred income taxes, net	1,005	1,023
Benefit obligations	84	91
Regulatory liabilities	1,295	1,298
Other	61	65
Total other liabilities	2,445	2,477
Long-term Debt:
VIE Securitization Bonds, net	817	977
Other long-term debt, net	3,972	3,281
Total long-term debt, net	4,789	4,258
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	2,486	1,896
Retained earnings	1,012	800
Accumulated other comprehensive income (loss)	(15)	(14)
Total shareholders’ equity	3,483	2,682
Total Liabilities and Shareholders’ Equity	11,463	10,507
CERC Corp [Member]
Current Assets:
Cash and cash equivalents	2	14
Accounts receivable, less bad debt reserve	428	894
Accounts and notes receivable–affiliated companies	100	120
Accrued unbilled revenues	83	268
Natural gas inventory	228	194
Materials and supplies	73	65
Non-trading derivative assets	120	100
Taxes receivable	4	0
Prepaid expenses and other current assets	36	115
Total current assets	1,074	1,770
Property, Plant and Equipment:
Property, plant and equipment	7,892	7,431
Less: accumulated depreciation and amortization	2,330	2,205
Property, plant and equipment, net	5,562	5,226
Other Assets:
Goodwill	867	867
Regulatory assets	189	181
Non-trading derivative assets	64	38
Other	173	132
Total other assets	1,293	1,218
Total Assets	7,929	8,214
Current Liabilities:
Accounts payable	393	856
Accounts and notes payable–affiliated companies	48	50
Taxes accrued	66	82
Interest accrued	31	38
Customer deposits	74	75
Non-trading derivative liabilities	44	102
Other	143	137
Total current liabilities	799	1,340
Other Liabilities:
Deferred income taxes, net	455	406
Non-trading derivative liabilities	18	5
Benefit obligations	95	93
Regulatory liabilities	1,221	1,227
Other	381	329
Total other liabilities	2,170	2,060
Long-term Debt:
Total long-term debt, net	2,477	2,371
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	2,015	2,015
Retained earnings	463	423
Accumulated other comprehensive income (loss)	5	5
Total shareholders’ equity	2,483	2,443
Total Liabilities and Shareholders’ Equity	7,929	8,214
Series A Preferred Stock [Member]
Shareholders’ Equity:
Preferred Stock, $0.01 par value	790	790
Series B Preferred Stock [Member]
Shareholders’ Equity:
Preferred Stock, $0.01 par value	$ 950	$ 950

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Cash and cash equivalents	$ 259.0	$ 4,231.0
Accounts receivable, less bad debt reserve	1,091.0	1,190.0
Bad debt reserve	21.0	18.0
Prepaid expenses and other current assets	156.0	192.0
Regulatory assets	$ 2,194.0	$ 1,967.0
Preferred stock par value (in dollars per share)	$ 0.01
Cumulative preferred stock authorized (in shares)	20,000,000
Common stock par value (in dollars per share)	$ 0.01	$ 0.01
Common stock authorized (in shares)	1,000,000,000	1,000,000,000
Common stock outstanding (in shares)	502,235,354	501,197,784
Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	$ 224.0	$ 335.0
Accounts receivable, less bad debt reserve	48.0	56.0
Prepaid expenses and other current assets	19.0	34.0
Regulatory assets	821.0	1,059.0
Houston Electric [Member]
Cash and cash equivalents	228.0	335.0
Bad debt reserve	1.0	1.0
Prepaid expenses and other current assets	30.0	61.0
Regulatory assets	951.0	1,124.0
Houston Electric [Member] \| Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	224.0	335.0
Accounts receivable, less bad debt reserve	48.0	56.0
Prepaid expenses and other current assets	19.0	34.0
Regulatory assets	821.0	1,059.0
CERC Corp [Member]
Cash and cash equivalents	2.0	14.0
Accounts receivable, less bad debt reserve	428.0	894.0
Bad debt reserve	16.0	17.0
Prepaid expenses and other current assets	36.0	115.0
Regulatory assets	$ 189.0	$ 181.0
Cumulative Preferred Stock [Member]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Cumulative preferred stock authorized (in shares)	20,000,000	20,000,000
Series A Preferred Stock [Member]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock aggregate liquidation preference	$ 800.0	$ 800.0
Preferred stock outstanding (in shares)	800,000	800,000
Series B Preferred Stock [Member]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock aggregate liquidation preference	$ 977.5	$ 977.5
Preferred stock outstanding (in shares)	977,500	977,500

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash Flows from Operating Activities:
Net income	$ 634	$ 248
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	987	982
Amortization of deferred financing costs	22	34
Amortization of intangible assets in non-utility cost of revenues	19	0
Deferred income taxes	8	33
Unrealized gain on marketable securities	(206)	(66)
Loss on indexed debt securities	216	316
Write-down of natural gas inventory	5	2
Equity in earnings of unconsolidated affiliates, net of distributions	13	(15)
Pension contributions	(94)	(67)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	521	355
Inventory	(85)	(10)
Taxes receivable	(69)	(38)
Accounts payable	(646)	(262)
Fuel cost recovery	68	53
Non-trading derivatives, net	(66)	63
Margin deposits, net	(33)	2
Interest and taxes accrued	(89)	(53)
Net regulatory assets and liabilities	(101)	44
Other current assets	31	11
Other current liabilities	(118)	16
Other assets	81	(3)
Other liabilities	(22)	24
Other operating activities, net	10	10
Net cash provided by operating activities	1,086	1,679
Cash Flows from Investing Activities:
Capital expenditures	(1,822)	(1,121)
Acquisitions, net of cash acquired	(5,991)	0
Distributions from unconsolidated affiliate in excess of cumulative earnings	0	30
Proceeds from sale of marketable securities	0	398
Other investing activities, net	38	19
Net cash used in investing activities	(7,775)	(674)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	0	(39)
Proceeds from (payments of) commercial paper, net	1,584	(1,551)
Proceeds from long-term debt, net	2,916	997
Payments of long-term debt	(1,225)	(368)
Debt issuance costs	(19)	(36)
Payment of dividends on Common Stock	(433)	(360)
Payment of dividends on Preferred Stock	(101)	0
Proceeds from issuance of Series A Preferred Stock, net	0	790
Distribution to ZENS note holders	0	(398)
Other financing activities, net	(14)	(5)
Net cash provided by (used in) financing activities	2,708	(970)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(3,981)	35
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	4,278	296
Cash, Cash Equivalents and Restricted Cash at End of Period	297	331
Houston Electric [Member]
Cash Flows from Operating Activities:
Net income	312	296
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	519	737
Amortization of deferred financing costs	8	8
Deferred income taxes	(39)	(24)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	(84)	(95)
Accounts receivable/payable–affiliated companies	(7)	(12)
Inventory	(9)	(10)
Taxes receivable	5	(9)
Accounts payable	3	(6)
Non-trading derivatives, net	(25)	0
Interest and taxes accrued	(28)	(50)
Net regulatory assets and liabilities	(58)	(66)
Other current assets	15	13
Other current liabilities	(3)	(9)
Other assets	8	4
Other liabilities	(13)	16
Other operating activities, net	(9)	(5)
Net cash provided by operating activities	595	788
Cash Flows from Investing Activities:
Capital expenditures	(744)	(678)
Increase in notes receivable–affiliated companies	(772)	0
Other investing activities, net	12	15
Net cash used in investing activities	(1,504)	(663)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	696	398
Payments of long-term debt	(390)	(368)
Increase (decrease) in notes payable–affiliated companies	(1)	15
Dividend to parent	(100)	(123)
Contribution from parent	590	0
Debt issuance costs	(8)	(4)
Other financing activities, net	(1)	0
Net cash provided by (used in) financing activities	786	(82)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(123)	43
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	370	274
Cash, Cash Equivalents and Restricted Cash at End of Period	247	317
CERC Corp [Member]
Cash Flows from Operating Activities:
Net income	159	175
Less: Income from discontinued operations, net of tax	0	140
Income from continuing operations	159	35
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	228	222
Amortization of deferred financing costs	8	7
Deferred income taxes	26	6
Write-down of natural gas inventory	5	2
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	653	449
Accounts receivable/payable–affiliated companies	(9)	0
Inventory	(47)	1
Taxes receivable	(4)	0
Accounts payable	(458)	(261)
Fuel cost recovery	68	53
Non-trading derivatives, net	(60)	60
Margin deposits, net	(33)	2
Interest and taxes accrued	(23)	(9)
Net regulatory assets and liabilities	(1)	73
Other current assets	11	7
Other current liabilities	(9)	24
Other assets	(3)	5
Other liabilities	2	(2)
Net cash provided by operating activities from continuing operations	513	674
Net cash provided by operating activities from discontinued operations	0	176
Net cash provided by operating activities	513	850
Cash Flows from Investing Activities:
Capital expenditures	(546)	(411)
Increase in notes receivable–affiliated companies	27	0
Other investing activities, net	4	5
Net cash used in investing activities from continuing operations	(515)	(406)
Net cash provided by investing activities from discontinued operations	0	47
Net cash used in investing activities	(515)	(359)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	0	(39)
Proceeds from (payments of) commercial paper, net	100	(800)
Proceeds from long-term debt, net	0	599
Increase (decrease) in notes payable–affiliated companies	0	(570)
Dividend to parent	(119)	(286)
Contribution from parent	0	600
Debt issuance costs	0	(5)
Other financing activities, net	(2)	(1)
Net cash used in financing activities from continuing operations	(21)	(502)
Net cash provided by financing activities from discontinued operations	0	0
Net cash provided by (used in) financing activities	(21)	(502)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(23)	(11)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	25	12
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 2	$ 1

Condensed Statements of Consolidated Changes in Equity - USD ($) $ in Millions	Total	Series A Preferred Stock [Member]	Series B Preferred Stock [Member]	Common Stock [Member]	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Retained Earnings [Member] Series A Preferred Stock [Member]	Retained Earnings [Member] Series B Preferred Stock [Member]	AOCI Attributable to Parent [Member]	CERC Corp [Member]	CERC Corp [Member] Common Stock [Member]	CERC Corp [Member] Additional Paid-in Capital [Member]	CERC Corp [Member] Retained Earnings [Member]	CERC Corp [Member] AOCI Attributable to Parent [Member]	Houston Electric [Member]	Houston Electric [Member] Common Stock [Member]	Houston Electric [Member] Additional Paid-in Capital [Member]	Houston Electric [Member] Retained Earnings [Member]	Houston Electric [Member] AOCI Attributable to Parent [Member]
Balance, beginning of period at Dec. 31, 2017					0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, New Issues		1,000,000
Balance, end of period at Sep. 30, 2018					1,000,000
Balance, beginning of period at Dec. 31, 2017						431,000,000							1,000					1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						0
Balance, end of period at Sep. 30, 2018						431,000,000							1,000					1,000
Balance, beginning of period at Dec. 31, 2017					$ 0	$ 4	$ 4,209	$ 543			$ (68)		$ 0	$ 2,528	$ 574	$ 6		$ 0	$ 1,696	$ 673	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Value, New Issues		$ 790
Issuances related to benefit and investment plans						0	12
Other Significant Noncash Transaction, Value of Consideration Given												$ (1,460)		(1,460)
Contribution From Parent														600					0
Other																			0
Net income (Loss)	$ 248							248				175			175		$ 296			296
Dividends, Common Stock, Cash				$ (360)				(240)
Dividend to parent															(286)					(123)
Other comprehensive income (loss)											10										7
Balance, end of period at Sep. 30, 2018	5,508				$ 790	$ 4	4,221	551			(58)	2,137	$ 0	1,668	463	6	2,549	$ 0	1,696	846	7
Balance, beginning of period at Jun. 30, 2018					0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, New Issues		1,000,000
Balance, end of period at Sep. 30, 2018					1,000,000
Balance, beginning of period at Jun. 30, 2018						431,000,000							1,000					1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						0
Balance, end of period at Sep. 30, 2018						431,000,000							1,000					1,000
Balance, beginning of period at Jun. 30, 2018					$ 0	$ 4	4,215	513			(62)		$ 0	2,528	529	6		$ 0	1,697	763	4
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Value, New Issues		$ 790
Issuances related to benefit and investment plans						0	6
Other Significant Noncash Transaction, Value of Consideration Given												(1,460)		(1,460)
Contribution From Parent														600					0
Other																			(1)
Net income (Loss)	158							158				9			9		143			143
Dividends, Common Stock, Cash								(120)
Dividend to parent															(75)					(60)
Other comprehensive income (loss)											4										3
Balance, end of period at Sep. 30, 2018	$ 5,508				$ 790	$ 4	4,221	551			(58)	2,137	$ 0	1,668	463	6	2,549	$ 0	1,696	846	7
Cumulative preferred stock authorized (in shares)	20,000,000
Balance, beginning of period at Dec. 31, 2018		800,000	977,500		2,000,000
Balance, end of period at Sep. 30, 2019		800,000	977,500		2,000,000
Balance, beginning of period at Dec. 31, 2018	501,197,784					501,000,000							1,000					1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						1,000,000
Balance, end of period at Sep. 30, 2019	502,235,354					502,000,000							1,000					1,000
Balance, beginning of period at Dec. 31, 2018	$ 8,058				$ 1,740	$ 5	6,072	349			(108)	2,443	$ 0	2,015	423	5	2,682	$ 0	1,896	800	(14)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						0	0
Other Significant Noncash Transaction, Value of Consideration Given												0
Contribution From Parent																			590
Other																			0
Net income (Loss)	634							634				159			159		312			312
Dividends, Common Stock, Cash				$ (433)				(289)
Dividends, Preferred Stock, Cash		$ (50)	$ (51)						$ (24)	$ (34)
Dividend to parent															(119)					(100)
Other comprehensive income (loss)											1										(1)
Balance, end of period at Sep. 30, 2019	$ 8,346				$ 1,740	$ 5	6,072	636			(107)	2,483	$ 0	2,015	463	5	3,483	$ 0	2,486	1,012	(15)
Balance, beginning of period at Jun. 30, 2019					2,000,000
Balance, end of period at Sep. 30, 2019		800,000	977,500		2,000,000
Balance, beginning of period at Jun. 30, 2019						502,000,000							1,000					1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						0
Balance, end of period at Sep. 30, 2019	502,235,354					502,000,000							1,000					1,000
Balance, beginning of period at Jun. 30, 2019					$ 1,740	$ 5	6,065	552			(105)		$ 0	2,015	486	5		$ 0	2,486	887	(15)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances related to benefit and investment plans						0	7
Other Significant Noncash Transaction, Value of Consideration Given												0
Contribution From Parent																			0
Other																			0
Net income (Loss)	$ 270							270				(7)			(7)		185			185
Dividends, Common Stock, Cash								(145)
Dividends, Preferred Stock, Cash									$ (24)	$ (17)
Dividend to parent															(16)					(60)
Other comprehensive income (loss)											(2)										0
Balance, end of period at Sep. 30, 2019	$ 8,346				$ 1,740	$ 5	$ 6,072	$ 636			$ (107)	$ 2,483	$ 0	$ 2,015	$ 463	$ 5	$ 3,483	$ 0	$ 2,486	$ 1,012	$ (15)
Cumulative preferred stock authorized (in shares)	20,000,000

Condensed Statements of Consolidated Changes in Equity (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Class of Stock [Line Items]
Cumulative preferred stock par value (in dollars per share) - Series A	$ 0.01		$ 0.01
Cumulative preferred stock shares authorized (in shares)	20,000,000	20,000,000	20,000,000	20,000,000
Common stock shares par value (in dollars per share)	$ 0.01	$ 0.01	$ 0.01	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,000,000,000	1,000,000,000	1,000,000,000	1,000,000,000	1,000,000,000
Common stock dividends declared per share	$ 0.2875	$ 0.2775	$ 0.5750	$ 0.5550
Series A Preferred Stock [Member]
Class of Stock [Line Items]
Cumulative preferred stock par value (in dollars per share) - Series A	0.01	0.01	0.01	0.01	$ 0.01
Preferred stock dividends declared	30.6250	0.0000	30.6250	0.0000
Series B Preferred Stock [Member]
Class of Stock [Line Items]
Cumulative preferred stock par value (in dollars per share) - Series A	0.01		0.01		$ 0.01
Preferred stock dividends declared	$ 17.5000	$ 0.0000	$ 35.0000	$ 0.0000

Background and Basis of Presentation

9 Months Ended

Sep. 30, 2019

Background and Basis of Presentation [Text Block]

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 last paragraph in Note 12 to the Registrants’ Condensed Consolidated 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 Combined Notes to the Unaudited Condensed Consolidated Financial Statements apply to all Registrants and specific references to Houston Electric and CERC herein also pertain to CenterPoint Energy, unless otherwise indicated. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the Registrants’ combined 2018 Form 10-K.

Background. CenterPoint Energy, Inc. is a public utility holding company and owns interests in Enable as described below. On the Merger Date, pursuant to the Merger Agreement, CenterPoint Energy consummated the previously announced Merger and acquired Vectren for approximately $6 billion in cash. On the Merger Date, Vectren became a wholly-owned subsidiary of CenterPoint Energy.

As of September 30, 2019, 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; and


•	CERC (i) owns and operates natural gas distribution systems in six states and (ii) obtains and offers competitive variable and fixed-price physical natural gas supplies and services primarily to commercial and industrial customers and electric and natural gas utilities in over 30 states through its wholly-owned subsidiary, CES.


•	Vectren holds three public utilities through its wholly-owned subsidiary, VUHI, a public utility holding company:


•	Indiana Gas provides energy delivery services to natural gas customers located in central and southern Indiana;


•	SIGECO provides energy delivery services to electric and natural gas customers located 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


•	VEDO provides energy delivery services to natural gas customers located near Dayton in west-central Ohio.


•	Vectren performs non-utility activities through:


•	Infrastructure Services, which provides underground pipeline construction and repair services through wholly-owned subsidiaries Miller Pipeline, LLC and Minnesota Limited, LLC and serves natural gas utilities across the United States, focusing on recurring integrity, station and maintenance work and opportunities for large transmission pipeline construction projects; and


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

As of September 30, 2019, CenterPoint Energy, indirectly through CNP Midstream, owned approximately 53.7% of the common units representing limited partner interests in Enable, 50% of the management rights and 40% of the incentive distribution rights in Enable GP and also directly owned an aggregate of 14,520,000 Enable Series A Preferred Units. Enable owns, operates and develops natural gas and crude oil infrastructure assets.

As of September 30, 2019, CenterPoint Energy and Houston Electric had VIEs consisting of the Bond Companies, which are consolidated. The consolidated VIEs are wholly-owned, bankruptcy-remote, special purpose entities that were formed solely for the purpose of securitizing transition and system restoration-related property. Creditors of CenterPoint Energy and Houston Electric have no recourse to any assets or revenues of the Bond Companies. The bonds issued by these VIEs are payable only from and secured by transition and system restoration property, and the bondholders have no recourse to the general credit of CenterPoint Energy or Houston Electric.

Basis of Presentation. The preparation of 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 and energy services, (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 presentation. See Note 9 for further discussion.

Concurrent with the completion of the Merger, CenterPoint Energy added two new reportable segments, Indiana Electric Integrated and Infrastructure Services, to its five reportable segments disclosed in the Registrants’ combined 2018 Form 10-K. Additionally, CenterPoint Energy’s Natural Gas Distribution reportable segment now includes the gas operations of SIGECO (Indiana South), Indiana Gas and VEDO and CenterPoint Energy’s Corporate and Other reportable segment now includes ESG. Houston Electric’s and CERC’s reportable segments were not impacted by the Merger. For a description of the Registrants’ reportable segments, see Note 16.

Significant Accounting Policies. In addition to the significant accounting policies disclosed in the Registrants’ combined 2018 Form 10-K, CenterPoint Energy has adopted the following new or enhanced significant accounting policies subsequent to the consummation of the Merger:

Principles of Consolidation. Businesses within the Infrastructure Services reportable segment provide underground pipeline construction and repair services for customers that include NGD utilities. In accordance with consolidation guidance in ASC 980—Regulated Operations, costs incurred by NGD utilities for these pipeline construction and repair services are not eliminated in consolidation when capitalized and included in rate base by the NGD utility.

Guarantees. CenterPoint Energy recognizes guarantee obligations at fair value. CenterPoint Energy discloses parent company guarantees of a subsidiary’s obligation when that guarantee results in the exposure of a material obligation of the parent company even if the probability of fulfilling such obligation is considered remote. See Note 14(b).

Income Taxes. Investment tax credits are deferred and amortized to income over the approximate lives of the related property.

MISO Transactions. Indiana Electric is a member of MISO. MISO-related purchase and sale transactions are recorded using settlement information provided by the MISO. These purchase and sale transactions are accounted for on at least a net hourly position, meaning net purchases within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility natural gas, fuel and purchased power, and net sales within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility revenues. On occasion, prior period transactions are resettled outside the routine process due to a change in the MISO’s tariff or a material interpretation thereof. Expenses associated with resettlements are recorded once the resettlement is probable and the resettlement amount can be estimated. Revenues associated with resettlements are recognized when the amount is determinable and collectability is reasonably assured.

Mergers and Acquisitions (CenterPoint Energy)

9 Months Ended

Sep. 30, 2019

Business Combinations [Abstract]

Mergers and Acquisitions (CenterPoint Energy) [Text Block]

Mergers and Acquisitions (CenterPoint Energy)

Merger with Vectren. On the Merger Date, pursuant to the Merger Agreement, CenterPoint Energy consummated the previously announced Merger and acquired Vectren for approximately $6 billion in cash. Each share of Vectren common stock issued and outstanding immediately prior to the closing was canceled and converted into the right to receive $72.00 in cash per share, without interest. At the closing, each stock unit payable in Vectren common stock or whose value is determined with reference to the value of Vectren common stock, whether vested or unvested, was canceled with cash consideration paid in accordance with the terms of the Merger Agreement. These amounts did not include a stub period cash dividend of $0.41145 per share, which was declared, with CenterPoint Energy’s consent, by Vectren’s board of directors on January 16, 2019, and paid to Vectren stockholders as of the record date of February 1, 2019.

Pursuant to the Merger Agreement and immediately subsequent to the close of the Merger, CenterPoint Energy cash settled $78 million in outstanding share-based awards issued prior to the Merger Date by Vectren to its employees. As a result of the Merger, CenterPoint Energy assumed a liability for these share-based awards of $41 million and recorded an incremental cost of $37 million in Operation and maintenance expenses on its Condensed Statements of Consolidated Income during the nine months ended September 30, 2019 for the accelerated vesting of the awards in accordance with the Merger Agreement.

Subsequent to the close of the Merger, CenterPoint Energy recognized severance totaling $61 million to employees terminated immediately subsequent to the Merger close, inclusive of change of control severance payments to executives of Vectren under existing agreements, and which is included in Operation and maintenance expenses on its Condensed Statements of Consolidated Income during the nine months ended September 30, 2019.

In connection with the Merger, VUHI and VCC made offers to prepay certain outstanding guaranteed senior notes as required pursuant to certain note purchase agreements previously entered into by VUHI and VCC. See Note 12 for further details.

Following the closing, shares of Vectren common stock, which previously traded under the ticker symbol “VVC” on the NYSE, ceased trading on and were delisted from the NYSE.

The Merger is being accounted for in accordance with ASC 805, Business Combinations, with CenterPoint Energy as the accounting acquirer of Vectren. Identifiable assets acquired and liabilities assumed have been recorded at their estimated fair values on the Merger Date.

Vectren’s regulated operations, comprised of electric generation and electric and natural gas energy delivery services, are subject to the rate-setting authority of the FERC, the IURC and the PUCO, and are accounted for pursuant to U.S. generally accepted accounting principles for regulated operations. The rate-setting and cost-recovery provisions currently in place for Vectren’s regulated operations provide revenues derived from costs including a return on investment of assets and liabilities included in rate base. Thus, the fair values of Vectren’s tangible and intangible assets and liabilities subject to these rate-setting provisions approximate their carrying values. Accordingly, neither the assets and liabilities acquired, nor the unaudited pro forma financial information, reflect any adjustments related to these amounts. The fair value of regulatory assets not earning a return have been determined using the income approach and are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs.

The fair value of Vectren’s assets acquired and liabilities assumed that are not subject to the rate-setting provisions, including identifiable intangibles, have been determined using the income approach and the market approach. The valuation of Vectren’s long-term debt is primarily considered a Level 2 fair value measurement. All other valuations are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in the future market prices.

The following table presents the preliminary purchase price allocation as of September 30, 2019 (in millions):



Cash and cash equivalents	$	16
Other current assets	598
Property, plant and equipment, net	5,146
Identifiable intangibles	322
Regulatory assets	338
Other assets	151
Total assets acquired	6,571
Current liabilities	690
Regulatory liabilities	944
Other liabilities	860
Long-term debt	2,401
Total liabilities assumed	4,895
Net assets acquired	1,676
Goodwill	4,306
Total purchase price consideration	$	5,982

CenterPoint Energy has not completed a final valuation analysis necessary to determine the fair market values of all of Vectren’s assets and liabilities or the allocation of its purchase price. The preliminary amounts may change as CenterPoint Energy completes its analysis of key valuation assumptions and various tax matters. The preliminary amounts are subject to revision to the extent that additional information is obtained about the facts and circumstances that existed as of the Merger Date. The final allocation could differ materially from this preliminary purchase price allocation and, as such, no assurances can be provided regarding the preliminary purchase accounting. The final allocation may include changes in the fair value of (1) property, plant and equipment,

(2) intangible assets and goodwill, (3) deferred taxes and (4) other assets and liabilities. Changes in the preliminary purchase price allocation since the initial estimates reported in the first quarter of 2019 primarily included additional information obtained related to intangible assets.

The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed is recognized as goodwill, which is primarily attributable to significant potential strategic benefits to CenterPoint Energy, including growth opportunities for more rate-regulated investment, more customers for existing products and services and additional products and services for existing customers. Additionally, CenterPoint Energy believes the Merger will increase geographic and business diversity as well as scale in attractive jurisdictions and economies. CenterPoint Energy anticipates that the value assigned to goodwill will not be deductible for tax purposes.

The estimated fair value of the identifiable intangible assets and related useful lives as included in the preliminary purchase price allocation include:



	Weighted Average Useful Lives	Estimated Fair Value
	(in years)	(in millions)
Operation and maintenance agreements	24	$	12
Customer relationships	18	220
Construction backlog	1	28
Trade names	10	62
Total		$	322

Amortization expense related to the operation and maintenance agreements and construction backlog was $7 million and $19 million for the three and nine months ended September 30, 2019, respectively, and is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Condensed Statements of Consolidated Income. Amortization expense related to customer relationships and trade names was $5 million and $13 million for the three and nine months ended September 30, 2019, respectively, and is included in Depreciation and amortization expense on CenterPoint Energy’s Condensed Statements of Consolidated Income.

The results of operations for Vectren included in CenterPoint Energy’s Interim Condensed Financial Statements from the Merger Date are as follows:



	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
	(in millions)
Operating revenues	$	756	$	1,917
Net income	67		86

The following unaudited pro forma financial information reflects the consolidated results of operations of CenterPoint Energy, assuming the Merger had taken place on January 1, 2018. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved had the Merger taken place on the dates indicated or of the future consolidated results of operations of the combined company.



	Three Months Ended September 30,					Nine Months Ended September 30,
	2019		2018			2019			2018
	(in millions)
Operating revenues	$	2,742	$	2,877		$	9,317		$	9,521
Net income	279		212		(1)	649		(2)	282		(3)


(1)	Pro forma net income was adjusted to exclude $18 million of Vectren Merger-related transaction costs incurred in 2018 and reflected in the historical income statements.


(2)	Pro forma net income was adjusted to exclude $37 million of Vectren Merger-related transaction costs incurred in 2019.


(3)	Pro forma net income was adjusted to include $38 million and $1 million, respectively, of Vectren and CenterPoint Energy Merger-related transaction costs incurred from October 1, 2018 to September 30, 2019.

CenterPoint Energy incurred integration costs in connection with the Merger of $19 million and $67 million for the three and nine months ended September 30, 2019, respectively, which were included in Operation and maintenance expenses in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Acquisition of Utility Pipeline Construction Company. An acquisition was made during the nine months ended September 30, 2019 by CenterPoint Energy’s Infrastructure Services reportable segment, resulting in goodwill and intangible assets of approximately $6 million and $8 million, respectively. The intangible assets primarily relate to backlog and customer relationships. The allocation of the $25 million purchase price is preliminary and subject to change. The results of operations for the acquired company have been included in the consolidated financial statements from the date of acquisition and are not significant to the consolidated financial results of CenterPoint Energy. Pro forma results of operations have not been presented for the acquisition because the effects of the acquisition were not significant to CenterPoint Energy’s consolidated financial results for all periods presented.

New Accounting Pronouncements

9 Months Ended

Sep. 30, 2019

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements [Text Block]

New Accounting Pronouncements

The following table provides an overview of certain recently adopted or issued accounting pronouncements applicable to all the Registrants, unless otherwise noted.



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Effective Date	Financial Statement Impact upon Adoption
ASU 2016-13- Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	This standard, including standards amending this standard, requires a new model called CECL to estimate credit losses for (1) financial assets subject to credit losses and measured at amortized cost and (2) certain off-balance sheet credit exposures. Upon initial recognition of the exposure, the CECL model requires an entity to estimate the credit losses expected over the life of an exposure based on historical information, current information and reasonable and supportable forecasts, including estimates of prepayments. Transition method: modified retrospective	January 1, 2020 Early adoption is permitted	The adoption of this standard may result in an adjustment to the carrying value of the Registrants’ accounts receivable. The Registrants do not anticipate the adoption of this standard will have a material impact on the Registrants’ financial position, results of operations or cash flows.
ASU 2018-13- Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement	This standard eliminates, modifies and adds certain disclosure requirements for fair value measurements. Transition method: prospective for additions and one modification and retrospective for all other amendments	Adoption of eliminations and modifications as of September 30, 2018; Additions will be adopted January 1, 2020	The adoption of this standard did not impact the Registrants’ financial position, results of operations or cash flows. Note 8 reflects the disclosures modified upon adoption.
ASU 2018-15- Intangibles-Goodwill and Other- Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns accounting for implementation costs incurred in a cloud computing arrangement that is accounted for as a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also prescribes the balance sheet, income statement, and cash flow classification of the capitalized implementation costs and related amortization expense and requires additional quantitative and qualitative disclosures. Transition method: retrospective or prospective	January 1, 2020 Early adoption is permitted	The adoption of this standard will require the Registrants to capitalize certain costs to implement cloud computing arrangements that are accounted for as service contracts within Prepaid expenses and other current assets on the Registrants’ condensed consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ condensed statements of consolidated income. The Registrants do not anticipate the adoption of this standard will have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures.

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.

Revenue Recognition

9 Months Ended

Sep. 30, 2019

Revenue from Contract with Customer [Abstract]

Revenue Recognition [Text Block]

Revenue Recognition

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.

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

CenterPoint Energy



	Three Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	861		$	165	$	518		$	81		$	377		$	91	$	2,093
Derivatives income	—			—		—			664			—			—		664
Other (3)	(2		)	—		6			—			—			2		6
Eliminations	—			—		(9		)	(11		)	(1		)	—		(21		)
Total revenues	$	859		$	165	$	515		$	734		$	376		$	93	$	2,742

	Nine Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1) (4)		Natural Gas Distribution (1) (4)			Energy Services (2)			Infrastructure Services (2) (4)			Corporate and Other (2) (4)		Total
	(in millions)
Revenue from contracts	$	2,319		$	388	$	2,581		$	341		$	849		$	210	$	6,688
Derivatives income	3			—		—			2,505			—			—		2,508
Other (3)	(9		)	—		2			—			—			5		(2		)
Eliminations	—			—		(29		)	(92		)	(2		)	—		(123		)
Total revenues	$	2,313		$	388	$	2,554		$	2,754		$	847		$	215	$	9,071



	Three Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	904		$	—	$	398		$	82		$	—	$	1	$	1,385
Derivatives income	—			—		—			838			—		—		838
Other (3)	(7		)	—		12			—			—		2		7
Eliminations	—			—		(8		)	(10		)	—		—		(18		)
Total revenues	$	897		$	—	$	402		$	910		$	—	$	3	$	2,212

	Nine Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,525		$	—	$	2,093		$	338		$	—	$	4	$	4,960
Derivatives income	(4		)	—		—			2,727			—		—		2,723
Other (3)	(19		)	—		(35		)	—			—		7		(47		)
Eliminations	—			—		(26		)	(57		)	—		—		(83		)
Total revenues	$	2,502		$	—	$	2,032		$	3,008		$	—	$	11	$	7,553


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)

Primarily consists of income from ARPs and leases. 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.


(4)	Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to September 30, 2019.

Houston Electric



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)
Revenue from contracts	$	861		$	904		$	2,319		$	2,525
Other (1)	(2		)	(7		)	(9		)	(19		)
Total revenues	$	859		$	897		$	2,310		$	2,506

(1)

CERC



	Three Months Ended September 30,
	2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	393		$	81		$	3	$	477		$	398		$	82		$	—	$	480
Derivatives income	—			664			—		664			—			838			—		838
Other (3)	5			—			—		5			12			—			—		12
Eliminations	(9		)	(11		)	—		(20		)	(8		)	(10		)	—		(18		)
Total revenues	$	389		$	734		$	3	$	1,126		$	402		$	910		$	—	$	1,312

	Nine Months Ended September 30,
	2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,101		$	341		$	4	$	2,446		$	2,093		$	338		$	—	$	2,431
Derivatives income	—			2,505			—		2,505			—			2,727			—		2,727
Other (3)	5			—			—		5			(35		)	—			—		(35		)
Eliminations	(29		)	(91		)	—		(120		)	(26		)	(57		)	—		(83		)
Total revenues	$	2,077		$	2,755		$	4	$	4,836		$	2,032		$	3,008		$	—	$	5,040


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)

Revenues from Contracts with Customers

Houston Electric T&D (CenterPoint Energy and Houston Electric). Houston Electric 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, 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 is recognized upon completion of service based on the tariff rates set by state regulators. 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 state regulators. Payments are received on a monthly basis.

Indiana Electric Integrated (CenterPoint Energy). Indiana Electric generates, distributes and transmits 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, is recognized as electricity is delivered and represents amounts both billed and unbilled. Customers are billed monthly and payment terms, set by the regulator, require payment within a month of billing.

Natural Gas Distribution (CenterPoint Energy and CERC). Natural gas is distributed and transported 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.

Energy Services (CenterPoint Energy and CERC). The majority of CES natural gas sales contracts are considered a derivative, as the contracts typically have a stated minimum or contractual volume of delivery.

For contracts in which CES delivers the full requirement of the natural gas needed by the customer and a volume is not stated, a contract as defined under ASC 606 is created upon the customer’s exercise of its option to take natural gas. CES supplies natural gas to retail customers over time as customers consume the natural gas when delivered. For wholesale customers, CES supplies natural gas at a point in time because the wholesale customer is presumed to have storage capabilities. Control is transferred to both types of customers upon delivery of natural gas. Revenue is recognized on a monthly basis based on the estimated volume of natural gas delivered and the price agreed upon with the customer. Payments are received on a monthly basis.

AMAs are natural gas sales contracts under which CES also assumes management of a customer’s physical storage and/or transportation capacity. AMAs have two distinct performance obligations, which consist of natural gas sales and natural gas delivery because delivery could occur separate from the sale of natural gas (e.g., from storage to customer premises). Most AMAs’ natural gas sales performance obligations are accounted for as embedded derivatives. The transaction price is allocated between the sale of natural gas and the delivery based on the stand-alone selling price as stated in the contract. CES performs natural gas delivery over time as customers take delivery of the natural gas and recognizes revenue on an aggregated monthly basis based on the volume of natural gas delivered and the fees stated within the contract. Payments are received on a monthly basis.

Infrastructure Services (CenterPoint Energy). Infrastructure Services provides underground pipeline construction and repair services. The contracts are generally less than one year in duration and consist of fixed price, unit, and time and material customer contracts. Under unit or time and material contracts, Infrastructure Services performs construction and repair services under specific work-orders at prices established by master service agreements. The performance obligation is defined at the work-order level. These services are billed to customers monthly or more frequently for work completed based on units completed or the costs of time and material incurred and generally require payment within 30 days of billing. Infrastructure Services has the right to consideration from customers in an amount that corresponds directly with the performance obligation satisfied, and therefore recognizes revenue at a point in time in the amount to which it has the right to invoice, which results in accrued unbilled revenues at the end of each accounting period.

Under fixed price contracts, Infrastructure Services performs larger scale construction and repair services. Each contract is typically accounted for as a single performance obligation. Services performed under fixed price contracts are typically billed per the terms of the contract, which can range from completion of specific milestones to scheduled billing intervals. Billings occur monthly or more frequently for work completed and generally require payment within 30 days of billing. Revenue for fixed price contracts is recognized over time as control is transferred using the input method, considering costs incurred relative to total expected cost. Total expected cost is therefore a significant judgment affecting the amount and timing of revenue recognition. Infrastructure Services’ revenues are not subject to significant returns, refunds or warranty obligations.

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. On an aggregate basis as of September 30, 2019, the Registrants’ contract assets primarily relate to contracts in the Infrastructure Services segment where revenue is recognized using the input method. The Registrants’ contract liabilities are included in Accounts payable and Other current liabilities in their Condensed Consolidated Balance Sheets. On an aggregate basis as of September 30, 2019, the Registrants’ contract liabilities primarily relate to ESG contracts where revenue is recognized using the input method.

The opening and closing balances of accounts receivable, other accrued unbilled revenue, contract assets and contract liabilities from contracts with customers for the nine months ended September 30, 2019 are as follows:

CenterPoint Energy



	Accounts Receivable		Other Accrued Unbilled Revenues			Contract Assets		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2018 (1)	$	763	$	575		$	37	$	47
Closing balance as of September 30, 2019	779		403			75		42
Increase (decrease)	$	16	$	(172	)	$	38	$	(5	)


(1)	Opening balances related to Vectren are as of February 1, 2019.

The amount of revenue recognized in the nine-month period ended September 30, 2019 that was included in the opening contract liability was $46 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, 2018	$	234	$	110	$	3
Closing balance as of September 30, 2019	325		136		4
Increase	$	91	$	26	$	1

The amount of revenue recognized in the nine-month period ended September 30, 2019 that was included in the opening contract liability was $3 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between Houston Electric’s performance and the customer’s payment.

CERC



	Accounts Receivable			Other Accrued Unbilled Revenues
	(in millions)
Opening balance as of December 31, 2018	$	282		$	263
Closing balance as of September 30, 2019	137			82
Decrease	$	(145	)	$	(181	)

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

Remaining Performance Obligations (CenterPoint Energy). The table below discloses (1) the aggregate amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of the end of the reporting period for contracts and (2) when CenterPoint Energy expects to recognize this revenue. Such contracts include fixed price contracts in the Infrastructure Services reportable segment.



	Rolling 12 Months		Thereafter		Total
	(in millions)
Revenue expected to be recognized on contracts in place as of September 30, 2019:
Fixed price (bid)	$	365	$	—	$	365
	$	365	$	—	$	365

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.

Employee Benefit Plans

9 Months Ended

Sep. 30, 2019

Retirement Benefits [Abstract]

Employee Benefit Plans [Text Block]

Employee Benefit Plans

As a result of the Merger, CenterPoint Energy now maintains three additional qualified defined benefit pension plans which are closed to new participants, a non-qualified SERP and a postretirement benefit plan. The defined benefit pension plans cover eligible full-time regular employees and retirees of Vectren and are primarily non-contributory. The postretirement benefit plan provides health care and life insurance benefits, which are a combination of self-insured and fully insured programs, to eligible Vectren retirees on both a contributory and non-contributory basis.

CenterPoint Energy, through its Infrastructure Services reportable segment, participates in several industry wide multi-employer pension plans for its collective bargaining employees which provide for monthly benefits based on length of service. The risks of participating in multi-employer pension plans are different from the risks of participating in single-employer pension plans in the following respects: (1) assets contributed to the multi-employer plan by one employer may be used to provide benefits

to employees of other participating employers, (2) if a participating employer stops contributing to the plan, the unfunded obligations of the plan allocable to such withdrawing employer may be borne by the remaining participating employers and (3) if CenterPoint Energy stops participation in some of its multi-employer pension plans, CenterPoint Energy may be required to pay those plans an amount based on its allocable share of the underfunded status of the plan, referred to as a withdrawal liability.

CenterPoint Energy, through Vectren, also acquired additional defined contribution retirement savings plans qualified under sections 401(a) and 401(k) of the Internal Revenue Code.

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,
	2019			2018			2019			2018
	(in millions)
Service cost (1)	$	10		$	10		$	30		$	28
Interest cost (2)	25			20			73			59
Expected return on plan assets (2)	(27		)	(27		)	(79		)	(80		)
Amortization of prior service cost (2)	2			3			6			7
Amortization of net loss (2)	13			10			39			32
Settlement cost (3) (2)	1			—			2			—
Curtailment gain (4) (2)	—			—			(1		)	—
Net periodic cost	$	24		$	16		$	70		$	46


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


(3)	A one-time, non-cash settlement cost is 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. CenterPoint Energy recognized a non-cash settlement cost of $1 million in June and September 2019, respectively, due to lump sum settlement payments.


(4)	A curtailment gain or loss is required when the expected future services of a significant number of employees are reduced or eliminated for the accrual of benefits. In February 2019, CenterPoint Energy recognized a pension curtailment gain of $1 million related to Vectren employees whose employment was terminated after the Merger closed.

Postretirement Benefits



	Three Months Ended September 30,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	2		$	—		$	—		$	—		$	—		$	1
Interest cost (2)	4			1			2			3			2			1
Expected return on plan assets (2)	(3		)	(1		)	—			(1		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(1		)	—			(1		)	(1		)	—
Net periodic cost (income)	$	2		$	(1	)	$	2		$	1		$	—		$	2

	Nine Months Ended September 30,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	3		$	—		$	1		$	1		$	—		$	1
Interest cost (2)	12			5			4			10			6			3
Expected return on plan assets (2)	(6		)	(3		)	(1		)	(4		)	(3		)	(1		)
Amortization of prior service cost (credit) (2)	(3		)	(4		)	—			(3		)	(4		)	1
Net periodic cost (income)	$	6		$	(2	)	$	4		$	4		$	(1	)	$	4


(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 contributions to be made to the pension and postretirement benefit plans during 2019:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2019	$	94	$	—	$	—
Expected contribution to postretirement benefit plans in 2019	20		10		4

The table below reflects the contributions made to the pension and postretirement benefit plans during 2019:



	Three Months Ended September 30, 2019						Nine Months Ended September 30, 2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	65	$	—	$	—	$	94	$	—	$	—
Postretirement benefit plans	4		3		1		12		8		3

Regulatory Matters

9 Months Ended

Sep. 30, 2019

Regulatory Assets and Liabilities, Other Disclosures [Abstract]

Regulatory Accounting [Text Block]

Regulatory Matters

The following is a list of regulatory assets and liabilities reflected on the Registrants’ respective Condensed Consolidated Balance Sheets:



	September 30, 2019									December 31, 2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	18		$	—		$	18		$	77		$	—		$	77
Non-current regulatory assets:
Securitized regulatory assets	821			821			—			1,059			1,059			—
Unrecognized equity return (2)	(175		)	(175		)	—			(213		)	(213		)	—
Unamortized loss on reacquired debt (3)	63			63			—			68			68			—
Pension and postretirement-related regulatory asset (3)	683			35			27			725			33			30
Hurricane Harvey restoration costs (3)	68			64			4			68			64			4
Regulatory assets related to TCJA (3) (4)	30			23			7			33			23			10
Asset retirement obligation (3)	139			25			92			109			24			85
Other regulatory assets-not earning a return (5)	154			65			46			81			55			26
Other regulatory assets	411			30			13			37			11			26
Total non-current regulatory assets	2,194			951			189			1,967			1,124			181
Total regulatory assets	2,212			951			207			2,044			1,124			258
Regulatory Liabilities:
Current regulatory liabilities (6)	31			—			28			38			17			21
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	1,606			830			449			1,323			847			476
Estimated removal costs	1,430			259			634			886			269			617
Other regulatory liabilities	445			206			138			316			182			134
Total non-current regulatory liabilities	3,481			1,295			1,221			2,525			1,298			1,227
Total regulatory liabilities	3,512			1,295			1,249			2,563			1,315			1,248
Total regulatory assets and liabilities, net	$	(1,300	)	$	(344	)	$	(1,042	)	$	(519	)	$	(191	)	$	(990	)


(1)	Current regulatory assets are included in Prepaid expenses and other current assets in the Registrants’ respective Condensed Consolidated Balance Sheets.

(2)

The unrecognized equity return will be recognized as it is recovered in rates through 2024. The timing of CenterPoint Energy’s and Houston Electric’s recognition of the equity return will vary each period based on amounts actually collected during the period. The actual amounts recognized are adjusted at least annually to correct any over-collections or under-collections during the preceding 12 months.



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Allowed equity return recognized	$	14	$	14	$	17	$	17	$	38	$	38	$	62	$	62


(3)	Substantially all of these regulatory assets are not earning a return.


(4)	The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities.


(5)	Regulatory assets acquired in the Merger and not earning a return were recorded at fair value as of the Merger Date. Such fair value adjustments are recognized over time until the regulatory asset is recovered.


(6)	Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Condensed Consolidated Balance Sheets.

Houston Electric Base Rate Case (CenterPoint Energy and Houston Electric)

On April 5, 2019, and subsequently adjusted in errata filings in May and June 2019, Houston Electric filed its base rate application with the PUCT and the cities in its service area seeking approval for revenue increases of approximately $194 million, exclusive of the EDIT refund discussed below.

The key proposals of the rate case include:


•	a rate base of $6.4 billion with a 50% debt, 50% equity capital structure and a 10.4% ROE;


•	a prudency determination on all capital investments made by Houston Electric since January 1, 2010;


•	the establishment of a rider to refund unprotected EDIT resulting from the TCJA; and


•	updated depreciation rates and approval to recover other costs.

On September 16, 2019, the ALJs issued a PFD recommending a revenue increase of approximately $2.6 million, which is lower than as filed primarily due to the recommended rate base and operation and maintenance expense disallowances, lower equity capital structure, and lower return on equity. If the PFD were approved in its entirety, it would result, among other things, in a one-time refund obligation of capital previously recovered through Houston Electric’s TCOS and DCRF mechanisms, and a pre-tax write-off of approximately $120 million for rate base disallowance of assets recorded in CenterPoint Energy’s and Houston Electric’s Condensed Consolidated Balance Sheets as of September 30, 2019. The amount of any refunds for previously recovered capital would be determined in a separate proceeding with the PUCT. Furthermore, the PFD recommends a separate proceeding with the PUCT to determine the amount, if any, of $158 million EDIT on Houston Electric’s securitized assets to be provided to customers.

The PUCT has not yet begun deliberating on the PFD, which is prepared by judges at a different state agency. A final order from the PUCT is currently expected in the fourth quarter of 2019, but motions for rehearing, if granted, could result in the order being issued in 2020. CenterPoint Energy and Houston Electric cannot predict the outcome of the proceeding.

CenterPoint Energy and Houston Electric record pre-tax expense for disallowed capital investments and customer refund obligations when the amounts are deemed both probable and estimable.

Derivative Instruments

9 Months Ended

Sep. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments [Text Block]

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 physical forward contracts, 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, through its Indiana Utilities, and CERC, through CES, enter into certain derivative instruments to mitigate the effects of commodity price movements. Certain financial instruments used to hedge portions of the natural gas inventory of the Energy Services reportable segment are designated as fair value hedges for accounting purposes. 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. For the impacts of cash flow hedges to Accumulated other comprehensive income, see Note 20.

The table below summarizes the Registrants’ outstanding interest rate hedging activity:



	September 30, 2019				December 31, 2018
Hedging Classification	Notional Principal
	CenterPoint Energy (1)		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Economic hedge	$	84	$	—	$	—	$	—
Cash flow hedge	—		—		450		450


(1)	Relates to interest rate derivative instruments at SIGECO.

Weather Hedges (CenterPoint Energy and CERC). CenterPoint Energy and CERC have weather normalization or other rate mechanisms that largely mitigate the impact of weather on NGD in Arkansas, Indiana, Louisiana, Mississippi, Minnesota, Ohio and Oklahoma, as applicable. CenterPoint Energy’s and CERC’s NGD 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 NGD 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 NGD’s results in Texas and on CenterPoint Energy’s electric operations’ results in its Texas and Indiana service territories.

CenterPoint Energy and CERC, as applicable, enter into winter season weather hedges from time to time for certain NGD jurisdictions and electric operations’ service territory to mitigate the effect of fluctuations from normal weather on results of operations and cash flows. These weather hedges are based on heating degree days at 10-year normal weather. Houston Electric and Indiana Electric do not enter into weather hedges.

The tables below summarize CenterPoint Energy’s and CERC’s current weather hedge gain (loss) activity:



	Three Months Ended September 30,
	2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC
	(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—	$	—
Electric operations	2018 – 2019	8		—		—		2017 – 2018	9		—		—
Total (1)				$	—	$	—				$	—	$	—



	Nine Months Ended September 30,
	2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy			CERC
	(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—		$	—
Electric operations	2018 – 2019	8		3		—		2017 – 2018	9		(4		)	—
Total (1)				$	3	$	—				$	(4	)	$	—


(1)	Weather hedge gains (losses) are recorded in Revenues in the Condensed Statements of Consolidated Income.


(b)	Derivative Fair Values and Income Statement Impacts

The following tables present information about derivative instruments and hedging activities. The first three tables provide a balance sheet overview of Derivative Assets and Liabilities, while the last two tables provide a breakdown of the related income statement impacts.

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as cash flow hedges:
Interest rate derivatives	Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	7		—		1		7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	69		154		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	13		68		16		25
Interest rate derivatives	Other Liabilities	—		15		—		—
Indexed debt securities derivative	Current Liabilities	—		817		—		601
Total CenterPoint Energy		$	277	$	1,057	$	220	$	833


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)

Natural gas contracts are presented on a net basis in CenterPoint Energy’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CenterPoint Energy’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.


(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

Houston Electric



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as cash flow hedges:
Interest rate derivatives	Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Total Houston Electric		$	—	$	—	$	—	$	24

CERC



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	$	7	$	—	$	1	$	7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	69		148		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	13		54		16		25
Total CERC		$	277	$	205	$	220	$	208


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)

Natural gas contracts are presented on a net basis in CERC’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CERC’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.


(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

Cumulative Basis Adjustment for Fair Value Hedges (CenterPoint Energy and CERC)



		September 30, 2019
	Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		CenterPoint Energy		CERC		CenterPoint Energy			CERC
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	42	$	42	$	(7	)	$	(7	)
Total		$	42	$	42	$	(7	)	$	(7	)



		December 31, 2018
	Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		CenterPoint Energy		CERC		CenterPoint Energy		CERC
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	57	$	57	$	1	$	1
Total		$	57	$	57	$	1	$	1

Offsetting of Natural Gas Derivative Assets and Liabilities (CenterPoint Energy and CERC)

CenterPoint Energy



	September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)
Current Assets: Non-trading derivative assets	$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(157		)	107			(50		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(68		)	36			(32		)	(25		)	20			(5		)
Total CenterPoint Energy	$	52		$	50		$	102		$	12		$	19		$	31

CERC



	September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)
Current Assets: Non-trading derivative assets	$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(151		)	107			(44		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(54		)	36			(18		)	(25		)	20			(5		)
Total CERC	$	72		$	50		$	122		$	12		$	19		$	31


(1)	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.


(2)	The derivative assets and liabilities on the Registrant’s respective Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

Income Statement Impact of Hedge Accounting Activity (CenterPoint Energy and CERC)



	Three Months Ended September 30,
	2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	852		$	687		$	864		$	864
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	2			2			1			1
Derivatives designated as hedging instruments	(2		)	(2		)	(1		)	(1		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(59		)	(59		)	6			6



	Nine Months Ended September 30,
	2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	3,013		$	2,627		$	2,927		$	2,927
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(8		)	(8		)	(13		)	(13		)
Derivatives designated as hedging instruments	8			8			13			13
Amounts excluded from effectiveness testing recognized in earnings immediately	(138		)	(138		)	(73		)	(73		)


(1)	Income statement impact associated with cash flow hedge activity is related to gains and losses reclassified from Accumulated other comprehensive income into income. Amounts are immaterial for each Registrant in the three and nine months ended September 30, 2019 and 2018, respectively.

CenterPoint Energy



		Three Months Ended September 30,						Nine Months Ended September 30,
	Income Statement Location	2019			2018			2019			2018
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (losses) in Non-utility revenues	$	69		$	2		$	159		$	70
Indexed debt securities derivative	Loss on indexed debt securities	(62		)	(44		)	(216		)	(316		)
Total CenterPoint Energy		$	7		$	(42	)	$	(57	)	$	(246	)

CERC



		Three Months Ended September 30,				Nine Months Ended September 30,
	Income Statement Location	2019		2018		2019		2018
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (losses) in Non-utility revenues	$	69	$	2	$	159	$	70
Total CERC		$	69	$	2	$	159	$	70


(c)	Credit Risk Contingent Features (CenterPoint Energy and CERC)

CenterPoint Energy and CERC enter into financial derivative contracts containing material adverse change provisions. These provisions could require CenterPoint Energy or CERC to post additional collateral if the S&P or Moody’s credit ratings of CenterPoint Energy, Inc. or its subsidiaries, including CERC Corp., are downgraded.



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position	$	1	$	1	$	1	$	1
Fair value of collateral already posted	—		—		—		—
Additional collateral required to be posted if credit risk contingent features triggered	1		1		—		—

Fair Value Measurements

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

Fair Value Measurements [Text Block]

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, as well as natural gas inventory that has been designated as the hedged item in a fair value hedge.

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. A market approach is utilized to value the Registrants’ Level 3 assets or liabilities. As of September 30, 2019, CenterPoint Energy’s and CERC’s Level 3 assets and liabilities are comprised of physical natural gas forward contracts and options. Level 3 physical natural gas forward contracts and options are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.38 to $6.09 per MMBtu for CenterPoint Energy and from $1.38 to $6.09 per MMBtu for CERC) as an unobservable input. CenterPoint Energy’s and CERC’s Level 3 physical natural gas forward contracts and options derivative assets and liabilities consist of both long and short positions (forwards and options). Forward price decreases (increases) as of September 30, 2019 would have resulted in lower (higher) values, respectively, for long forwards and options and higher (lower) values, respectively, for short forwards and options.

The Registrants determine the appropriate level for each financial asset and liability on a quarterly basis. The Registrants also recognize purchases of Level 3 financial assets and liabilities at their fair market value at the end of the reporting period.

The following tables present information about the Registrants’ assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of September 30, 2019 and December 31, 2018 and indicate the fair value hierarchy of the valuation techniques utilized by the Registrants to determine such fair value.

CenterPoint Energy



	September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	748	$	—	$	—	$	—		$	748	$	542	$	—	$	—	$	—		$	542
Investments, including money market funds (2)	50		—		—		—			50		66		—		—		—			66
Natural gas derivatives (3)(4)	—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	798	$	234	$	43	$	(93	)	$	982	$	609	$	173	$	47	$	(82	)	$	747
Liabilities
Indexed debt securities derivative	$	—	$	817	$	—	$	—		$	817	$	—	$	601	$	—	$	—		$	601
Interest rate derivatives	—		15		—		—			15		24		—		—		—			24
Natural gas derivatives (3)(4)	—		203		22		(143		)	82		—		191		17		(101		)	107
Hedged portion of natural gas inventory	7		—		—		—			7		—		—		—		—			—
Total liabilities	$	7	$	1,035	$	22	$	(143	)	$	921	$	24	$	792	$	17	$	(101	)	$	732

Houston Electric



	September 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Netting		Total		Level 1		Level 2		Level 3		Netting		Total
Assets	(in millions)
Investments, including money market funds (2)	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Total assets	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Liabilities
Interest rate derivatives	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24

CERC



	September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	2	$	—	$	—	$	—		$	2	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)(4)	—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	13	$	234	$	43	$	(93	)	$	197	$	14	$	173	$	47	$	(82	)	$	152
Liabilities
Natural gas derivatives (3)(4)	$	—	$	183	$	22	$	(143	)	$	62	$	—	$	191	$	17	$	(101	)	$	107
Hedged portion of natural gas inventory	7		—		—		—			7		—		—		—		—			—
Total liabilities	$	7	$	183	$	22	$	(143	)	$	69	$	—	$	191	$	17	$	(101	)	$	107


(1)	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy and CERC to settle positive and negative positions and also include cash collateral posted with the same counterparties as follows:



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	50	$	50	$	19	$	19


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


(3)	Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

(4)

Level 1 natural gas derivatives include exchange-traded derivatives cleared by the CME, which deems that financial instruments cleared by the CME are settled daily in connection with posted cash payments. As a result of this exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes and are presented in Level 1 net of posted cash; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.

The following table presents additional information about assets or liabilities, including derivatives that are measured at fair value on a recurring basis for which CenterPoint Energy and CERC have utilized Level 3 inputs to determine fair value:



	Three Months Ended September 30,												Nine Months Ended September 30,
	2019						2018						2019						2018
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	20		$	20		$	(628	)	$	13		$	30		$	30		$	(622	)	$	46
Total gains	4			4			1			1			16			16			4			4
Total settlements	(1		)	(1		)	(1		)	(1		)	(18		)	(18		)	(36		)	(36		)
Transfers into Level 3	—			—			—			—			(1		)	(1		)	(2		)	(2		)
Transfers out of Level 3	(2		)	(2		)	650			9			(6		)	(6		)	678			10
Ending balance (1)	$	21		$	21		$	22		$	22		$	21		$	21		$	22		$	22

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:
	$	2		$	2		$	11		$	11		$	13		$	13		$	9		$	9


(1)	CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during the three or nine months ended September 30, 2019 or 2018.

Estimated Fair Value of Financial Instruments

The fair values of cash and cash equivalents, investments in debt and equity securities classified as “trading” 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, CenterPoint Energy’s ZENS indexed debt securities derivative and hedging instruments 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, 2019				December 31, 2018
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
CenterPoint Energy
Long-term debt, including current maturities (1)	$	14,861	$	15,994	$	9,140	$	9,308
Houston Electric
Long-term debt, including current maturities (1)	$	5,018	$	5,595	$	4,717	$	4,770
CERC
Long-term debt, including current maturities	$	2,477	$	2,783	$	2,371	$	2,488

(1)

Includes Securitization Bonds debt.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Equity Method Investments and Joint Ventures [Abstract]

Unconsolidated Affiliate (CenterPoint Energy and CERC)

9 Months Ended

Sep. 30, 2019

Unconsolidated Affiliate (CenterPoint Energy and CERC) [Text Block]

Unconsolidated Affiliates (CenterPoint Energy and CERC)

CenterPoint Energy has the ability to significantly influence the operating and financial policies of Enable, a publicly traded MLP, and, accordingly, accounts for its investment in Enable’s common units using the equity method of accounting. Enable is considered to be a VIE because the power to direct the activities that most significantly impact Enable’s economic performance does not reside with the holders of equity investment at risk. However, CenterPoint Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. As of September 30, 2019, CenterPoint Energy’s maximum exposure to loss related to Enable is limited to its investment in unconsolidated affiliate, its investment in Enable Series A Preferred Units and outstanding current accounts receivable from Enable.

Investment in Unconsolidated Affiliates (CenterPoint Energy):



	September 30, 2019		December 31, 2018
	(in millions)
Enable	$	2,467	$	2,482
Other (1)	2		—
Total	$	2,469	$	2,482


(1)	Represents the equity investment in ProLiance Holdings, LLC related primarily to an investment in LA Storage, LLC, a joint venture in a development project for salt-cavern natural gas storage, which was acquired in the Merger. This presentation reflects preliminary fair value of the equity investment on the acquisition date and is subject to change. See Note 3.

CenterPoint Energy evaluates its equity method investments for impairment when factors indicate that a decrease in value of its investment has occurred and the carrying amount of its investment may not be recoverable. An impairment loss is recognized in earnings when an impairment is deemed to be other than temporary. As of September 30, 2019, CenterPoint Energy’s investment in Enable is $10.55 per unit and Enable’s common unit price closed at $12.03 per unit (approximately $347 million above carrying value). The lowest close price for Enable’s common units in October 2019 was $10.07, which was approximately $112 million below carrying value. CenterPoint Energy performed an analysis of its investment in Enable as of September 30, 2019 and determined it will recover the value of its investment of $2.5 billion.

Limited Partner Interest and Units Held in Enable (CenterPoint Energy):



	September 30, 2019
	Limited Partner Interest (1)		Common Units (2)	Enable Series A Preferred Units (3)
CenterPoint Energy	53.7	%	233,856,623	14,520,000
OGE	25.5	%	110,982,805	—
Public unitholders	20.8	%	90,310,731	—
Total units outstanding	100.0	%	435,150,159	14,520,000


(1)	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.


(2)	Held indirectly through CNP Midstream by CenterPoint Energy.


(3)	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of September 30, 2019 and $363 million as of December 31, 2018. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods.

Generally, sales to any person or entity (including a series of sales to the same person or entity) of more than 5% of the aggregate of the common units CenterPoint Energy owns in Enable or sales to any person or entity (including a series of sales to the same person or entity) by OGE of more than 5% of the aggregate of the common units it owns in Enable are subject to mutual rights of first offer and first refusal set forth in Enable’s Agreement of Limited Partnership.

Interests Held in Enable GP (CenterPoint Energy):



	September 30, 2019
	Management Rights (1)		Incentive Distribution Rights (2)
CenterPoint Energy (3)	50	%	40	%
OGE	50	%	60	%


(1)	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.

(2)

Enable is expected to pay a minimum quarterly distribution of $0.2875 per common unit on its outstanding common units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to Enable GP and its affiliates, within 60 days after the end of each quarter. If cash distributions to Enable’s unitholders exceed $0.330625 per common unit in any quarter, Enable GP will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances Enable GP will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election. To date, no incentive distributions have been made.


(3)	Held indirectly through CNP Midstream.

Distributions Received from Enable (CenterPoint Energy and CERC):

CenterPoint Energy



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.3305	$	77	$	0.3180	$	74	$	0.9665	$	226	$	0.9540	$	223
Enable Series A Preferred Units	0.6250		9		0.6250		9		1.8750		27		1.8750		27
Total CenterPoint Energy			$	86			$	83			$	253			$	250

CERC



	Three Months Ended September 30, 2018				Nine Months Ended September 30, 2018
	Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.3180	$	74	$	0.9540	$	223
Total CERC			$	74			$	223


(1)	Prior to the Internal Spin in September 2018, distributions from Enable were received by CERC. After such date, distributions from Enable were received by CenterPoint Energy.

Transactions with Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
CenterPoint Energy
Natural gas expenses, including transportation and storage costs (1)	$	26	$	23	$	89	$	89
Reimbursement of support services (2)	—		1		3		4
CERC
Natural gas expenses, including transportation and storage costs (1)	26		23		89		89
Reimbursement of support services (2)	—		1		3		4


(1)	Included in Non-utility costs of revenues, including natural gas on CenterPoint Energy’s and CERC’s respective Condensed Statements of Consolidated Income.


(2)	Represents amounts billed for certain support services provided to Enable. Actual support services costs are recorded net of reimbursement.



	September 30, 2019		December 31, 2018
	(in millions)
CenterPoint Energy
Accounts payable for natural gas purchases from Enable	$	9	$	11
Accounts receivable for amounts billed for services provided to Enable	3		2
CERC
Accounts payable for natural gas purchases from Enable	9		11
Accounts receivable for amounts billed for services provided to Enable	3		2

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019			2018
	(in millions)
Operating revenues	$	699	$	928	$	2,229		$	2,481
Cost of sales, excluding depreciation and amortization	263		516		958			1,335
Depreciation and amortization	108		100		323			292
Operating income	175		171		507			436
Net income attributable to Enable common units	123		129		351			320
Reconciliation of Equity in Earnings (Losses), net:
CenterPoint Energy’s interest	$	66	$	70	$	189		$	173
Basis difference amortization (1)	11		11		35			35
Loss on dilution, net of proportional basis difference recognition	—		—		(11		)	—
CenterPoint Energy’s equity in earnings, net	$	77	$	81	$	213		$	208


(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 original investment in Enable and its underlying equity in net assets of Enable. The basis difference is being amortized through the year 2048.

Summarized unaudited consolidated balance sheet information for Enable is as follows:



	September 30, 2019			December 31, 2018
	(in millions)
Current assets	$	417		$	449
Non-current assets	12,018			11,995
Current liabilities	819			1,615
Non-current liabilities	4,076			3,211
Non-controlling interest	37			38
Preferred equity	362			362
Accumulated other comprehensive loss	(4		)	—
Enable partners’ equity	7,145			7,218
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,838		$	3,896
CenterPoint Energy’s basis difference	(1,371		)	(1,414		)
CenterPoint Energy’s equity method investment in Enable	$	2,467		$	2,482

Discontinued Operations (CERC):

On September 4, 2018, CERC completed the Internal Spin. CERC executed the Internal Spin to, among other things, enhance the access of CERC and CenterPoint Energy to low cost debt and equity through increased transparency and understandability of the financial statements, improve CERC’s credit quality by eliminating the exposure to Enable’s midstream business and provide clarity of internal reporting and performance metrics to enhance management’s decision making for CERC and CNP Midstream.

The Internal Spin represents a significant strategic shift that has a material effect on CERC’s operations and financial results and, as a result, CERC’s distribution of its equity investment in Enable met the criteria for discontinued operations classification. CERC has no continuing involvement with Enable other than its natural gas purchases from Enable. Therefore, CERC’s equity in earnings and related income taxes have been classified as Income from discontinued operations, net of tax, in CERC’s Condensed Statements of Consolidated Income for the periods presented. The following table presents amounts included in Income from discontinued operations, net of tax in CERC’s Condensed Statements of Consolidated Income.



		Three months ended September 30, 2018		Nine months ended September 30, 2018
	(in millions)
Equity in earnings of unconsolidated affiliate, net		$	57	$	184
Income tax expense		13		44
Income from discontinued operations, net of tax		$	44	$	140

Goodwill and Other Intangibles (CenterPoint Energy and CERC)

9 Months Ended

Sep. 30, 2019

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangibles (CenterPoint Energy and CERC) [Text Block]

Goodwill and Other Intangibles (CenterPoint Energy and CERC)

CenterPoint Energy’s goodwill by reportable segment as of December 31, 2018 and changes in the carrying amount of goodwill as of September 30, 2019 is as follows:



	December 31, 2018		Additions (1)		September 30, 2019
	(in millions)
Indiana Electric Integrated	$	—	$	1,008	$	1,008
Natural Gas Distribution	746		2,529		3,275
Energy Services (2)	110		—		110
Infrastructure Services	—		355		355
Corporate and Other	11		420		431
Total	$	867	$	4,312	$	5,179


(1)	The allocation of goodwill to reportable segments subsequent to the Merger is preliminary and subject to change. See Note 3.


(2)	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

CERC’s goodwill by reportable segment as of September 30, 2019 and December 31, 2018 is as follows:



	September 30, 2019		December 31, 2018
	(in millions)
Natural Gas Distribution	$	746	$	746
Energy Services (1)	110		110
Corporate and Other	11		11
Total	$	867	$	867


(1)	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

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 estimated fair value of the reporting unit is primarily determined based on an income approach or a weighted combination of income and market approaches. If the carrying amount is in excess of the estimated fair value of the reporting unit, then the excess amount is the impairment charge that should be recorded, not to exceed the carrying amount of goodwill. See Note 2.

CenterPoint Energy and CERC performed the annual goodwill impairment test in the third quarter of 2019 and determined that no goodwill impairment charge was required for any reporting unit. The reporting units approximate the reportable segments, with the exception of ESG, which is a separate reporting unit but included in CenterPoint Energy’s Corporate and Other reportable segment.

The tables below present information on CenterPoint Energy’s other intangible assets recorded in Intangible assets, net 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, unless otherwise indicated.



	September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships (1)	$	306	$	(40	)	$	266	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1
Trade names (1)	62		(4		)	58		—		—			—
Construction backlog (1) (2)	28		(18		)	10		—		—			—
Operation and maintenance agreements (1) (2)	12		(1		)	11		—		—			—
Other (1)	24		(14		)	10		16		(11		)	5
Total	$	436	$	(80	)	$	356	$	106	$	(41	)	$	65


(1)	The fair value of intangible assets acquired through acquisitions is preliminary and subject to change. See Note 3.


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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization (1)	$	7	$	2	$	20	$	7
Amortization expense of intangible assets recorded in Non-utility cost of revenues, including natural gas (2)	7		—		19		—


(1)	Includes $5 million and $13 million for the three and nine months ended September 30, 2019, respectively, of amortization expense related to intangibles acquired in the Merger. The fair value of intangible assets, and related amortization

assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.


(2)	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.

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



	September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships	$	86	$	(31	)	$	55	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1
Other	16		(14		)	2		16		(11		)	5
Total	$	106	$	(48	)	$	58	$	106	$	(41	)	$	65



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	2	$	2	$	7	$	7

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



	Amortization Expense
	CenterPoint Energy		CERC
	(in millions)
Remaining three months of 2019	$	15	$	4
2020	32		6
2021	31		6
2022	32		6
2023	31		5
2024	29		5

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy)

9 Months Ended

Sep. 30, 2019

Investments, Debt and Equity Securities [Abstract]

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) [Text Block]

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy)

(a) Investment in Securities Related to ZENS

A subsidiary of CenterPoint Energy holds shares of certain securities detailed in the table below, which are classified as trading securities and are expected to be held to facilitate CenterPoint Energy’s ability to meet its obligation under the ZENS. Unrealized gains and losses resulting from changes in the market value of the ZENS-Related Securities are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income.



	Shares Held
	September 30, 2019	December 31, 2018
AT&T Common	10,212,945	10,212,945
Charter Common	872,503	872,912

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1.0 billion of which $828 million remained outstanding as of September 30, 2019. 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, 2019	December 31, 2018
	(in shares)
AT&T Common	0.7185	0.7185
Charter Common	0.061382	0.061382

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 ZENS-Related Securities. 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 ZENS-Related Securities is less than or more than 2.309%. The adjusted principal amount is defined in the ZENS instrument as “contingent principal.” As of September 30, 2019, the ZENS, having an original principal amount of $828 million and a contingent principal amount of $80 million, were outstanding and were exchangeable at the option of the holders for cash equal to 95% of the market value of the ZENS-Related Securities.

Short-Term Borrowings and Long-term Debt

9 Months Ended

Sep. 30, 2019

Debt Disclosure [Abstract]

Short-term Borrowings and Long-term Debt [Text Block]

Short-term Borrowings and Long-term Debt


(a)	Short-term Borrowings (CenterPoint Energy and CERC)

Inventory Financing. NGD has AMAs associated with its utility distribution service in Arkansas, Louisiana, Mississippi, Oklahoma and Texas. The AMAs have varying terms, the longest of which expires in 2021. Pursuant to the provisions of the agreements, NGD sells natural gas and agrees to repurchase an equivalent amount of natural gas during the winter heating seasons at the same cost. These transactions are accounted for as an inventory financing. CenterPoint Energy and CERC had no outstanding obligations related to the AMAs as of both September 30, 2019 and December 31, 2018.


(b)	Long-term Debt

Debt Transactions. During the nine months ended September 30, 2019, the following debt instruments were issued or incurred:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of September 30, 2019		Maturity Date
			(in millions)
Houston Electric	January 2019	General mortgage bonds	$	700	4.25	%	2049
CenterPoint Energy (1)	February 2019	Variable rate term loan	25		2.88	%	2020
CenterPoint Energy	May 2019	Variable rate term loan	1,000		2.81	%	2021
CenterPoint Energy	August 2019	Unsecured senior notes	500		2.50	%	2024
CenterPoint Energy	August 2019	Unsecured senior notes	400		2.95	%	2030
CenterPoint Energy	August 2019	Unsecured senior notes	300		3.70	%	2049


(1)	Draw down by VCC on its variable rate term loan.

Proceeds from Houston Electric’s debt issuance were used for general limited liability company purposes, including capital expenditures. Proceeds from VCC’s draw down of its term loan were used for general corporate purposes. Proceeds from CenterPoint Energy’s debt issuances were used for general corporate purposes, including the repayment of commercial paper.

Acquired Debt (CenterPoint Energy). The table below summarizes the long-term external debt of Vectren and its subsidiaries that remained outstanding as of September 30, 2019:



	(in millions)
Long-term debt:
Senior notes due 2020 to 2045 (1)	$	637
Variable rate term loan due 2020 (2)	300
Variable rate term loan due 2020 (3)	200
First mortgage bonds due 2022 to 2055 (4)	293
Commercial paper (5)	278
Bank revolver (6)	—
Total Vectren debt	$	1,708

(1)

Consists of $532 million of senior notes issued by VUHI, $96 million of senior notes issued by Indiana Gas, and $9 million of senior notes issued by VCC. The senior notes have stated interest rates that range from 3.33% to 7.08%. The senior notes issued by VUHI are guaranteed by SIGECO, Indiana Gas and VEDO. The senior notes issued by VCC are guaranteed by Vectren. In connection with the Merger, two of CenterPoint Energy’s acquired wholly-owned subsidiaries, VUHI and VCC, made offers to prepay certain outstanding guaranteed senior notes as required pursuant to certain note purchase agreements previously entered into by VUHI and VCC. In turn, VUHI and VCC borrowed $568 million and $191 million, respectively, from CenterPoint Energy to fund note redemptions effected pursuant to these prepayment offers. To fund these prepayments and payments of approximately $5 million of accrued interest, CenterPoint Energy issued approximately $764 million of commercial paper.


(2)	Issued by VUHI and guaranteed by SIGECO, Indiana Gas and VEDO. As of September 30, 2019, the term loan was fully drawn upon. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread ranging from 70 to 90 basis points depending on credit rating.


(3)	Issued by VCC and guaranteed by Vectren. As of September 30, 2019, the term loan was fully drawn upon, exclusive of any potential incremental term loans under the related facility’s accordion feature. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread of 70 basis points.


(4)	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture. The first mortgage bonds have stated interest rates that range from 2.375% to 6.72%.


(5)	Issued by VUHI with maturities up to 30 days.


(6)	Represents borrowings under the VCC credit facility, which is guaranteed by Vectren.

Maturities (CenterPoint Energy). As of September 30, 2019, maturities of CenterPoint Energy’s long-term debt were as follows:



	(in millions)
Remaining three months of 2019	$	69
2020	831
2021	2,761
2022	2,998
2023	713
2024	1,184
2025 and thereafter	6,447

Credit Facilities. The Registrants had the following revolving credit facilities as of September 30, 2019:



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, 2019 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	3,300	1.500%	65%	(3)	58.6%	March 3, 2022
July 14, 2017	CenterPoint Energy (4)	400		1.125%	65%		52.9%	July 14, 2022
July 14, 2017	CenterPoint Energy (5)	200		1.250%	65%		57.1%	July 14, 2022
March 3, 2016	Houston Electric	300		1.125%	65%	(3)	48.7%	March 3, 2022
March 3, 2016	CERC	900		1.250%	65%		47.5%	March 3, 2022
	Total	$	5,100


(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 from 65% 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)	This credit facility was issued by VUHI, is guaranteed by SIGECO, Indiana Gas and VEDO and includes a $10 million swing line sublimit and a $20 million letter of credit sublimit. This credit facility backstops VUHI’s commercial paper program.


(5)	This credit facility was issued by VCC, is guaranteed by Vectren and includes a $40 million swing line sublimit and an $80 million letter of credit sublimit.

The Registrants, including the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of September 30, 2019.

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



	September 30, 2019								December 31, 2018
Registrant	Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate
	(in millions, except weighted average interest rate)
CenterPoint Energy (1)	$	—	$	6	$	1,383	2.28	%	$	—	$	6	$	—	—	%
CenterPoint Energy (2)	—		—		278		2.30	%	—		—		—		—
CenterPoint Energy (3)	—		—		—		—	%	—		—		—		—
Houston Electric	—		—		—		—	%	—		4		—		—
CERC	—		1		310		2.28	%	—		1		210		2.93	%
Total	$	—	$	7	$	1,971			$	—	$	11	$	210


(1)	CenterPoint Energy’s outstanding commercial paper generally has maturities of 60 days or less.


(2)	This credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.


(3)	This credit facility was issued by VCC and is guaranteed by Vectren.

Other. As of September 30, 2019, certain financial institutions agreed to issue, from time to time, up to $50 million of letters of credit on behalf of Vectren and certain of its subsidiaries in exchange for customary fees. These agreements to issue letters of credit expire on December 31, 2019. As of September 30, 2019, such financial institutions had issued $21 million of letters of credit on behalf of Vectren and certain of its subsidiaries.

Houston Electric had $68 million and $68 million of general mortgage bonds outstanding as of September 30, 2019 and December 31, 2018, respectively, as collateral for long-term debt of CenterPoint Energy that matures in 2028. These bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.

Income Taxes

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Income Taxes [Text Block]

Income Taxes

The Registrants reported the following effective tax rates:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
CenterPoint Energy (1)	19	%	24	%	15	%	26	%
Houston Electric (2)	18	%	20	%	18	%	21	%
CERC - Continuing operations (3) (4)	13	%	5	%	14	%	29	%
CERC - Discontinued operations (5)	n/a		23	%	n/a		24	%

(1)

CenterPoint Energy’s lower effective tax rate for the three and nine months ended September 30, 2019 compared to the same periods for 2018 was primarily due to the following: an increase in the amount of amortization of the net regulatory EDIT liability; the effect of state tax law changes that resulted in the remeasurement of state deferred taxes; and the impact of changes in valuation allowances on certain state net operating losses.


(2)	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2019 compared to the same periods for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability.

(3)

CERC’s higher effective tax rate on loss from continuing operations for the three months ended September 30, 2019 compared to the same period for 2018 was primarily due to a decrease in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the absence of a change in the valuation allowance on certain state net operating losses in the three months ended September 30, 2019, the effects of which are compounded by the book loss in the three months ended September 30, 2019.


(4)	CERC’s lower effective tax rate on income from continuing operations for the nine months ended September 30, 2019 compared to the same period for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the impact of changes in the valuation allowances on certain state net operating losses in 2019.


(5)	CERC’s effective tax rate on income from discontinued operations for the three and nine months ended September 30, 2018 was a result of the 21% federal income tax rate plus allocable state income taxes. There are no comparable periods in 2019 since the Internal Spin was completed in the third quarter of 2018.

The Registrants reported a net uncertain tax liability inclusive of interest and penalties of less than $1 million as of September 30, 2019, which reflects a release of approximately $1 million following the completion of Vectren’s 2016 IRS audit. No significant changes to the uncertain tax liability are expected over the next twelve months. For legacy CenterPoint Energy, tax years through 2016 have been audited and settled with the IRS; however, CenterPoint Energy filed amended returns for 2014 and 2015 to claim additional tax credits that are currently under review by the IRS. For the 2017 - 2019 tax years, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

Commitments and Contingencies

9 Months Ended

Sep. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies [Text Block]

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 Distribution and Energy Services reportable segments and CenterPoint Energy’s Indiana Electric Integrated reportable segment. Contracts with minimum payment provisions have various quantity requirements and durations and are not classified as non-trading derivative

assets and liabilities in CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets as of September 30, 2019 and December 31, 2018. 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.

As of September 30, 2019, minimum purchase obligations are approximately:



	CenterPoint Energy		CERC
	(in millions)
Remaining three months of 2019	$	217	$	160
2020	745		528
2021	614		429
2022	412		235
2023	330		177
2024	265		169
2025 and beyond	1,846		1,483

Indiana Electric Integrated also has other purchased power agreements that do not have minimum thresholds but do require payment when energy is generated by the provider. Costs arising from certain of these commitments are pass-through costs, generally collected dollar-for-dollar from retail customers through regulator-approved cost recovery mechanisms.


(b)	Guarantees and Product Warranties (CenterPoint Energy)

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

Specific to ESG’s role as a general contractor in the performance contracting industry, as of September 30, 2019, there were 63 open surety bonds supporting future performance with an aggregate face amount of approximately $627 million. ESG’s exposure is less than the face amount of the surety bonds and is limited to the level of uncompleted work under the contracts. As of September 30, 2019, approximately 35% of the work was yet to be completed on projects with open surety bonds. Further, various subcontractors issue surety bonds to ESG. In addition to these performance obligations, ESG also warrants the functionality of certain installed infrastructure generally for one year and the associated energy savings over a specified number of years. Since ESG’s inception in 1994, CenterPoint Energy believes ESG has had a history of generally meeting its performance obligations and energy savings guarantees and its installed products operating effectively. CenterPoint Energy assessed the fair value of its obligation for such guarantees as of September 30, 2019 and no amounts were recorded on CenterPoint Energy’s Condensed Consolidated Balance Sheets. The Merger purchase price allocation, including the fair value of liabilities for guarantees on the Merger Date, remains preliminary. See Note 3.

CenterPoint Energy issues parent company level guarantees to certain vendors, customers and other commercial counterparties of ESG. 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, 2019, CenterPoint Energy, primarily through Vectren, has issued parent company level guarantees supporting ESG’s obligations. For those obligations where potential exposure can be estimated, management estimates the maximum exposure under these guarantees to be approximately $498 million as of September 30, 2019. This exposure primarily relates to energy savings guarantees on federal energy savings performance contracts. Other parent company level guarantees, certain of which do not contain a cap on potential liability, have been issued in support of federal operations and maintenance projects for which a maximum exposure cannot be estimated based on the nature of the projects. While there can be no assurance that performance under any of these parent company guarantees will not be required in the future, CenterPoint Energy considers the likelihood of a material amount being incurred as remote.


(c)	Legal, Environmental and Other Matters

Legal Matters

Gas Market Manipulation Cases (CenterPoint Energy and CERC). CenterPoint Energy, its predecessor, Reliant Energy, and certain of their former subsidiaries were named as defendants in a large number of lawsuits filed against numerous gas market participants in a number of federal and western state courts in connection with the operation of the natural gas markets in 2000-2002. CenterPoint Energy and its affiliates were released or dismissed from all such cases, except for one case in federal court in Nevada

in which CES, a subsidiary of CERC, was a defendant. Plaintiffs in that case alleged a conspiracy to inflate Wisconsin natural gas prices in 2000-2002. In October 2018, CES reached an agreement to settle all claims against CES and CES’s claims for indemnity. During the third quarter of 2019, the federal district court issued final approval of the settlement and dismissed the case, and CES completed the required settlement payments; the settlement agreement has now become final. This settlement did not have a material adverse effect on CenterPoint Energy’s or CERC’s financial condition, results of operations or cash flows.

Minnehaha Academy (CenterPoint Energy and CERC). On August 2, 2017, a natural gas explosion occurred at the Minnehaha Academy in Minneapolis, Minnesota, resulting in the deaths of two school employees, serious injuries to others and significant property damage to the school. CenterPoint Energy, certain of its subsidiaries, including CERC, and the contractor company working in the school have been named in litigation arising out of this incident. CenterPoint Energy and CERC have reached confidential settlement agreements with some claimants. Additionally, CenterPoint Energy and CERC are cooperating with the ongoing investigation conducted by the National Transportation Safety Board. Further, CenterPoint Energy and CERC contested and have since reached a settlement regarding approximately $200,000 in fines imposed by the Minnesota Office of Pipeline Safety. In early 2018, the Minnesota Occupational Safety and Health Administration concluded its investigation without any adverse findings against CenterPoint Energy or CERC. CenterPoint Energy’s and CERC’s general and excess liability insurance policies provide coverage for third party bodily injury and property damage claims.

Litigation Related to the Merger (CenterPoint Energy). With respect to the Merger, in July 2018, seven separate lawsuits were filed against Vectren and the individual directors of Vectren’s Board of Directors in the U.S. District Court for the Southern District of Indiana. These lawsuits alleged violations of Sections 14(a) of the Exchange Act and SEC Rule 14a-9 on the grounds that the Vectren Proxy Statement filed on June 18, 2018 was materially incomplete because it omitted material information concerning the Merger. In August 2018, the seven lawsuits were consolidated, and the Court denied the plaintiffs’ request for a preliminary injunction. In October 2018, the plaintiffs filed their Consolidated Amended Class Action Complaint. In December 2018, two plaintiffs voluntarily dismissed their lawsuits. In September 2019, the court granted the defendants’ motion to dismiss and dismissed the remaining plaintiffs’ claims with prejudice, which the plaintiffs appealed in October 2019. The defendants believe that the allegations asserted are without merit and intend to vigorously defend themselves against the claims raised. CenterPoint Energy does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows.

Environmental Matters

MGP Sites. CenterPoint Energy, CERC and their predecessors operated MGPs in the past. In addition, certain of CenterPoint Energy’s subsidiaries acquired through the Merger 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 all costs which they presently are 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). 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 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 five 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, 2019
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	9	$	7
Minimum estimated remediation costs	7		4
Maximum estimated remediation costs	51		32
Minimum years of remediation	5		30
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. While the EPA Phase I Reconsideration moves forward, the existing CCR compliance obligations remain in effect. In August 2019, the EPA proposed additional amendments to its CCR Rule with respect to beneficial reuse of ash and other materials. The proposed revisions would not restrict Indiana Electric’s current beneficial reuse of its fly ash.

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, with bottom ash handling conversions completed. 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. In March 2018, Indiana Electric began posting ground water data monitoring reports annually to its public website in accordance with the requirements of the CCR Rule. This data preliminarily 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 is required to cease disposal of new ash in the ponds and commence closure of the ponds by October 31, 2020. CenterPoint Energy plans to seek extensions available under the CCR Rule that would allow Indiana Electric to continue to use the ponds through December 31, 2023. The inability to take these extensions may result in increased and potentially significant operational costs in connection with the accelerated implementation of an alternative ash disposal system or adversely impact Indiana Electric’s future operations. Failure to comply with these requirements could also result in an enforcement proceeding including the imposition of fines and penalties. 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 commenced closure activities. CenterPoint Energy believes the language in the IURC order is favorable for future recovery of closure costs for Indiana Electric’s remaining ponds.

Indiana Electric continues to refine site specific estimates of closure costs. In March 2019, Indiana Electric entered into agreements with third parties for the excavation and beneficial reuse of the ash at the A.B. Brown ash pond. 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 the ponded ash. 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. Any

proceeds received will offset costs that have been and will be incurred to close the ponds. On November 4, 2019, the EPA released a pre-publication copy of proposed revisions to the CCR Rule. CenterPoint Energy will evaluate the proposals to determine potential impacts to current compliance plans for its A.B. Brown and F.B. Culley generating stations.

As of September 30, 2019, CenterPoint Energy has recorded an approximate $75 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 the anticipated outcome of the aforementioned insurance proceeding. In addition to these removal costs, Indiana Electric also anticipates equipment purchases of between $60 million and $80 million to complete the A.B. Brown closure project.

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.

Earnings Per Share (CenterPoint Energy)

9 Months Ended

Sep. 30, 2019

Earnings Per Share [Abstract]

Earnings Per Share (CenterPoint Energy) [Text Block]

Earnings Per Share (CenterPoint Energy)

The following table reconciles numerators and denominators of CenterPoint Energy’s basic and diluted earnings per common share. Basic earnings per common share is determined by dividing Income available to common shareholders - basic by the Weighted average common shares outstanding - basic for the applicable period. Diluted earnings per common share is determined by the inclusion of potentially dilutive common stock equivalent shares that may occur if securities to issue Common Stock were exercised or converted into Common Stock.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions, except share and per share amounts)
Numerator:
Income available to common shareholders - basic	$	241	$	153	$	546	$	243
Add back: Series B Preferred Stock dividend	—		—		—		—
Income available to common shareholders - diluted	$	241	$	153	$	546	$	243

Denominator:
Weighted average common shares outstanding - basic	502,228,000		431,554,000		501,986,000		431,437,000
Plus: Incremental shares from assumed conversions:
Restricted stock	2,852,000		3,337,000		2,852,000		3,337,000
Series B Preferred Stock (1)	—		—		—		—
Weighted average common shares outstanding - diluted	505,080,000		434,891,000		504,838,000		434,774,000

Earnings per common share:
Basic earnings per common share	$	0.48	$	0.35	$	1.09	$	0.56
Diluted earnings per common share	$	0.47	$	0.35	$	1.08	$	0.56

(1)

The potentially dilutive impact from Series B Preferred Stock applies the if-converted method in calculating diluted earnings per common share. Under this method, diluted earnings per common share is adjusted for the more dilutive effect of the Series B Preferred Stock as a result of either its accumulated dividend for the period in the numerator or the assumed-converted common share equivalent in the denominator. The computation of diluted earnings per common share outstanding for the three and nine months ended September 30, 2019 excludes Series B Preferred Stock dividends of $17 million and $51 million, respectively, and 33,537,000 and 33,537,000 potentially dilutive shares, respectively, because to include them would be anti-dilutive. However, these could be potentially dilutive in the future.

Reportable Business Segments

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

Reportable Business Segments [Text Block]

Reportable Segments

The Registrants’ determination of reportable segments considers the strategic operating units under which the Registrants manage sales, allocate resources and assess performance of various products and services to wholesale or retail customers in differing regulatory environments. The Registrants use operating income as the measure of profit or loss for the reportable segments other than Midstream Investments, where equity in earnings is used.

As of September 30, 2019, reportable segments by Registrant were as follows:

Registrants

Houston Electric T&D

Indiana Electric Integrated

Natural Gas Distribution

Energy

Services

Infrastructure Services

Midstream Investments

Corporate and Other

CenterPoint Energy

Houston Electric

CERC


•	The Houston Electric T&D reportable segment consists of electric transmission and distribution services in the Texas Gulf Coast area.


•	The Indiana Electric Integrated reportable segment consists of electric transmission and distribution services primarily to southwestern Indiana and includes power generation and wholesale power operations.


•	CenterPoint Energy’s Natural Gas Distribution reportable segment consists of intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Arkansas, Indiana, Louisiana, Minnesota, Mississippi, Ohio, Oklahoma and Texas.


•	CERC’s Natural Gas Distribution reportable segment consists of intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Arkansas, Louisiana, Minnesota, Mississippi, Oklahoma and Texas.

•The Energy Services reportable segment consists of non-rate regulated natural gas sales and services operations.

•The Infrastructure Services reportable segment consists of underground pipeline construction and repair services.


•	The Midstream Investments reportable segment consists of the equity investment in Enable (excluding the Enable Series A Preferred Units).


•	CenterPoint Energy’s Corporate and Other reportable segment consists of energy performance contracting and sustainable infrastructure services through ESG and other corporate operations which support all of the business operations of CenterPoint Energy.


•	CERC’s Corporate and Other reportable segment consists primarily of corporate operations which support all of the business operations of CERC.

Financial data for reportable segments is as follows:

CenterPoint Energy



	Three Months Ended September 30,
	2019								2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Houston Electric T&D	$	859	(1)	$	—		$	269	$	897	(1)	$	—		$	227
Indiana Electric Integrated	165			—			48		—			—			—
Natural Gas Distribution	515			9			27		402			8			3
Energy Services	734			11			2		910			10			(9		)
Infrastructure Services	376			1			42		—			—			—
Midstream Investments (2)	—			—			—		—			—			—
Corporate and Other	93			—			4		3			—			5
Eliminations	—			(21		)	—		—			(18		)	—
Consolidated	$	2,742		$	—		$	392	$	2,212		$	—		$	226



	Nine Months Ended September 30,
	2019									2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Houston Electric T&D	$	2,313	(1)	$	—		$	522		$	2,502	(1)	$	—		$	523
Indiana Electric Integrated	388			—			64			—			—			—
Natural Gas Distribution	2,554			29			241			2,032			26			166
Energy Services	2,754			92			64			3,008			57			(20		)
Infrastructure Services	847			2			50			—			—			—
Midstream Investments (2)	—			—			—			—			—			—
Corporate and Other	215			—			(17		)	11			—			(5		)
Eliminations	—			(123		)	—			—			(83		)	—
Consolidated	$	9,071		$	—		$	924		$	7,553		$	—		$	664


(1)	Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192


(2)	CenterPoint Energy’s Midstream Investments’ equity in earnings, net are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Enable	$	77	$	81	$	213	$	208

Houston Electric

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

included.


(1)	Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192

CERC



	Three Months Ended September 30,
	2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	389	$	9		$	20	$	402	$	8		$	3
Energy Services	734		11			2		910		10			(9		)
Other Operations	3		—			1		—		—			(1		)
Eliminations	—		(20		)	—		—		(18		)	—
Consolidated	$	1,126	$	—		$	23	$	1,312	$	—		$	(7	)



	Nine Months Ended September 30,
	2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	2,077	$	29		$	212	$	2,032	$	26		$	166
Energy Services	2,755		91			64		3,008		57			(20		)
Corporate and Other	4		—			1		—		—			—
Eliminations	—		(120		)	—		—		(83		)	—
Consolidated	$	4,836	$	—		$	277	$	5,040	$	—		$	146

CenterPoint Energy and CERC



	Total Assets
	September 30, 2019							December 31, 2018
	CenterPoint Energy				CERC			CenterPoint Energy				CERC
	(in millions)
Houston Electric T&D	$	11,463			$	—		$	10,509			$	—
Indiana Electric Integrated (1)	3,009				—			—				—
Natural Gas Distribution (1)	13,235				7,018			6,956				6,956
Energy Services	1,264				1,264			1,558				1,558
Infrastructure Services (1)	1,284				—			—				—
Midstream Investments	2,529				—			2,482				—
Corporate and Other (1)	4,884			(2)	121			6,156			(2)	66
Eliminations	(3,026		)		(474		)	(652		)		(366		)
Consolidated	$	34,642			$	7,929		$	27,009			$	8,214


(1)	Total assets by reportable segment include assets acquired in the Merger, which are based on preliminary fair value estimates and allocations on the acquisition date and are subject to change. See Note 3.

(2)

Includes pension and other postemployment-related regulatory assets of $625 million and $665 million, respectively, as of September 30, 2019 and December 31, 2018. Additionally, total assets as of December 31, 2018 included $3.9 billion of temporary investments included in Cash and cash equivalents on CenterPoint Energy’s Consolidated Balance Sheets.

Supplemental Disclosure of Cash Flow Information

9 Months Ended

Sep. 30, 2019

Supplemental Cash Flow Elements [Abstract]

Supplemental Disclosure of Cash Flow Information [Text Block]

Supplemental Disclosure of Cash Flow Information

The table below provides supplemental disclosure of cash flow information:



	Nine Months Ended September 30,
	2019						2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	364	$	203	$	88	$	301	$	173	$	85
Income taxes, net	174		93		3		89		122		3
Non-cash transactions:
Accounts payable related to capital expenditures	178		91		75		140		87		66
Capital distribution associated with the Internal Spin	—		—		—		—		—		1,460
ROU assets obtained in exchange for lease liabilities (1)	43		1		28		—		—		—


(1)	Includes the transition impact of adoption of ASU 2016-02 Leases.

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, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash and cash equivalents	$	259	$	228	$	2	$	4,231	$	335	$	14
Restricted cash included in Prepaid expenses and other current assets	38		19		—		46		34		11
Restricted cash included in Other	—		—		—		1		1		—
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	297	$	247	$	2	$	4,278	$	370	$	25

Related Party Transactions (Houston Electric and CERC)

9 Months Ended

Sep. 30, 2019

Related Party Transactions (Houston Electric and CERC)

Houston Electric and CERC participate in a 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 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 money pool activity:



	September 30, 2019						December 31, 2018
	Houston Electric			CERC			Houston Electric			CERC
	(in millions, except interest rates)
Money pool investments (borrowings) (1)	$	772		$	87		$	(1	)	$	114
Weighted average interest rate	2.32		%	2.32		%	2.42		%	2.42		%


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

Houston Electric and CERC affiliate related net interest income (expense) were as follows:



	Three Months Ended September 30,									Nine Months Ended September 30,
	2019				2018					2019				2018
	Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Interest income (expense) (1)	$	5	$	1	$	1	$	(2	)	$	14	$	3	$	1	$	(4	)


(1)	Interest income is included in Other income (expense), net and interest expense is included in Interest and other finance charges on Houston Electric’s and CERC’s respective Condensed Statements of Consolidated Income.

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 negotiated 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,
	2019					2018					2019					2018
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	38		$	31	$	47		$	36	$	132		$	106	$	138		$	105
Net affiliate service charges (billings)	(3		)	3		(3		)	3		(7		)	7		(8		)	8

Infrastructure Services provides pipeline construction and repair services to CERC. Amounts charged for operation and maintenance expenses by Infrastructure Services to CERC were not significant from February 1, 2019 to September 30, 2019. Additionally, CERC, through CES, sells natural gas to Indiana Electric for use in electric generation activities. Amounts charged by CERC to Indiana Electric were not significant from February 1, 2019 to September 30, 2019.

The table below presents transactions among Houston Electric, CERC and their parent, Utility Holding.



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	60	$	16	$	60	$	75	$	100	$	119	$	123	$	286
Cash contribution from parent	—		—		—		600		590		—		—		600
Capital distribution to parent associated with the Internal Spin	—		—		—		1,460		—		—		—		1,460

Leases

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Leases [Text Block]

Leases

The Registrants adopted ASC 842, Leases, and all related amendments on January 1, 2019 using the modified retrospective transition method and elected not to recast comparative periods in the year of adoption as permitted by the standard. There was no adjustment to retained earnings as a result of transition. As a result, disclosures for periods prior to adoption will be presented in accordance with accounting standards in effect for those periods. The Registrants also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed them to carry forward the historical lease classification. Additionally, the Registrants elected the practical expedient related to land easements, which allows the carry forward of the accounting treatment for land easements on existing agreements. The total ROU assets obtained in exchange for new operating lease liabilities upon adoption were $30 million, $1 million and $27 million for CenterPoint Energy, Houston

Electric and CERC, respectively. The Merger was completed on February 1, 2019, and as such the amounts recorded upon adoption are exclusive of Vectren’s leases.

An arrangement is determined to be a lease at inception based on whether the Registrant has the right to control the use of an identified asset. ROU assets represent the Registrants’ right to use the underlying asset for the lease term and lease liabilities represent the Registrants’ obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Registrants are the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. Each Registrant uses the implicit rate for agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

The Registrants have lease agreements with lease and non-lease components and have elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings. For classes of leases in which lease and non-lease components are not combined, consideration is allocated between components based on the stand-alone prices. Variable payments are not significant to the Registrants.

The Registrants’ lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties. Agreements in which the Registrants are lessors do not include provisions for the lessee to purchase the assets. Because risk is minimal, the Registrants do not take any significant actions to manage risk associated with the residual value of their leased assets.

The Registrants’ lease agreements are primarily equipment and real property leases, including land and office facility leases. The Registrants’ lease terms may include options to extend or terminate a lease when it is reasonably certain that those options will be exercised. Operating lease payments exclude approximately $16 million of legally-binding undiscounted minimum lease payments for leases signed but not yet commenced. The Registrants have elected an accounting policy that exempts leases with terms of one year or less from the recognition requirements of ASU 842.

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,						Nine Months Ended September 30,
	2019						2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	8	$	—	$	1	$	19	$	—	$	4
Short-term lease cost	23		7		—		46		12		—
Variable lease cost	1		—		—		1		—		—
Total lease cost	$	32	$	7	$	1	$	66	$	12	$	4

Supplemental balance sheet information related to leases was as follows:



	September 30, 2019
	CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	67		$	1		$	25
Total leased assets	$	67		$	1		$	25
Liabilities:
Current operating lease liability (2)	$	21		$	—		$	4
Non-current operating lease liability (3)	46			1			21
Total leased liabilities	$	67		$	1		$	25

Weighted-average remaining lease term (in years) - operating leases	5.2			5.4			7.9
Weighted-average discount rate - operating leases	3.41		%	3.51		%	3.66		%


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


(2)	Reported within Current other liabilities in the Condensed Consolidated Balance Sheets.


(3)	Reported within Other liabilities in the Condensed Consolidated Balance Sheets.

As of September 30, 2019, maturities of operating lease liabilities were as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remaining three months of 2019	$	6	$	—	$	1
2020	22		1		5
2021	15		—		5
2022	9		—		4
2023	7		—		3
2024	3		—		2
2025 and beyond	12		—		9
Total lease payments	74		1		29
Less: Interest	7		—		4
Present value of lease liabilities	$	67	$	1	$	25

The following table sets forth information concerning the Registrants’ obligations under non-cancelable long-term operating leases as of December 31, 2018:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2019	$	6	$	1	$	5
2020	6		—		5
2021	5		—		4
2022	4		—		4
2023	3		—		3
2024 and beyond	12		—		11
Total (1)	$	36	$	1	$	32


(1)	The Merger was completed on February 1, 2019. As such, these amounts are exclusive of Vectren’s leases.

As of September 30, 2019, maturities of undiscounted operating lease payments to be received are as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remaining three months of 2019	$	1	$	—	$	—
2020	2		1		—
2021	2		—		—
2022	2		—		—
2023	2		—		—
2024	2		—		—
2025 and beyond	10		—		—
Total lease payments to be received	$	21	$	1	$	—

Other information related to leases is as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019						2019
	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	$	6	$	—	$	2	$	18	$	1	$	4

Equity

9 Months Ended

Sep. 30, 2019

Equity [Abstract]

Equity [Text Block]

Equity

Dividends Declared and Paid (CenterPoint Energy)

CenterPoint Energy paid dividends on its Common Stock during the nine months ended September 30, 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 21, 2019	March 14, 2019	$	0.2875	$	144
April 25, 2019	May 16, 2019	June 13, 2019	0.2875		144
July 31, 2019	August 15, 2019	September 12, 2019	0.2875		145
Total 2019			$	0.8625	$	433

December 13, 2017	February 15, 2018	March 8, 2018	$	0.2775	$	120
April 26, 2018	May 17, 2018	June 14, 2018	0.2775		120
July 26, 2018	August 16, 2018	September 13, 2018	0.2775		120
Total 2018			$	0.8325	$	360

CenterPoint Energy declared no dividends on its Series A Preferred Stock or Series B Preferred Stock during the three or nine months ended September 30, 2018.

CenterPoint Energy paid dividends on its Series A Preferred Stock during the nine months ended September 30, 2019 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	32.1563	$	26
July 31, 2019	August 15, 2019	September 3, 2019	30.6250		24
Total 2019			$	62.7813	$	50

CenterPoint Energy paid dividends on its Series B Preferred Stock during the nine months ended September 30, 2019 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	17.5000	$	17
April 25, 2019	May 15, 2019	June 3, 2019	17.5000		17
July 31, 2019	August 15, 2019	September 3, 2019	17.5000		17
Total 2019			$	52.5000	$	51

Dividend Requirement on Preferred Stock (CenterPoint Energy)



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Series A Preferred Stock	$	12	$	5	$	37	$	5
Series B Preferred Stock	17		—		51		—
Total preferred stock dividend requirement	$	29	$	5	$	88	$	5

Accumulated Other Comprehensive Income (Loss)

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



	Three Months Ended September 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric		CERC
	(in millions)
Beginning Balance	$	(105	)	$	(15	)	$	5	$	(62	)	$	4	$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(2		)	—			—		4			3		—
Other comprehensive loss from unconsolidated affiliates	(2		)	—			—		—			—		—
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	2			—			—		2			—		—
Tax expense	—			—			—		(2		)	—		—
Net current period other comprehensive income	(2		)	—			—		4			3		—
Ending Balance	$	(107	)	$	(15	)	$	5	$	(58	)	$	7	$	6



	Nine Months Ended September 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning Balance	$	(108	)	$	(14	)	$	5	$	(68	)	$	—		$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(3		)	(1		)	—		8			8			—
Other comprehensive loss from unconsolidated affiliates	(2		)	—			—		—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—		1			—			—
Actuarial losses (2)	6						—		5			—			—
Reclassification of deferred loss from cash flow hedges realized in net income	1			—			—		—			—			—
Tax expense	(2		)	—			—		(4		)	(1		)	—
Net current period other comprehensive income (loss)	1			(1		)	—		10			7			—
Ending Balance	$	(107	)	$	(15	)	$	5	$	(58	)	$	7		$	6

(1)

Gains and losses are reclassified from Accumulated other comprehensive income into income when the hedged transactions affect earnings. The reclassification amounts are included in Interest and other finance charges in each of the Registrants’ respective Statements of Consolidated Income. Over the next twelve months estimated amortization from Accumulated Comprehensive Income into income is expected to be immaterial.

(2)

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

Subsequent Events (CenterPoint Energy)

9 Months Ended

Sep. 30, 2019

Subsequent Events [Abstract]

Subsequent Events (CenterPoint Energy) [Text Block]

Subsequent Events (CenterPoint Energy)

CenterPoint Energy Dividend Declarations



Equity Instrument	Declaration Date	Record Date	Payment Date	Per Share
Common Stock	October 17, 2019	November 21, 2019	December 12, 2019	$	0.2875
Series B Preferred Stock	October 17, 2019	November 15, 2019	December 2, 2019	17.5000

Enable Distributions Declarations (CenterPoint Energy)

Equity Instrument

Declaration Date

Record Date

Payment Date

Per Unit Distribution

Expected Cash Distribution

(in millions)

Enable common units

November 5, 2019

November 19, 2019

November 26, 2019

0.3305

Enable Series A Preferred Units

November 5, 2019

November 14, 2019

0.6250

Background and Basis of Presentation (Policies) - Vectren [Member]	9 Months Ended
	Sep. 30, 2019
Principles of Consolidation [Policy Text Block]	Principles of Consolidation. Businesses within the Infrastructure Services reportable segment provide underground pipeline construction and repair services for customers that include NGD utilities. In accordance with consolidation guidance in ASC 980—Regulated Operations, costs incurred by NGD utilities for these pipeline construction and repair services are not eliminated in consolidation when capitalized and included in rate base by the NGD utility.
Product Warranties, Performance Guarantees & Other Guarantees [Policy Text Block]	Guarantees. CenterPoint Energy recognizes guarantee obligations at fair value. CenterPoint Energy discloses parent company guarantees of a subsidiary’s obligation when that guarantee results in the exposure of a material obligation of the parent company even if the probability of fulfilling such obligation is considered remote. See Note 14(b).
Income Taxes [Policy Text Block]	Income Taxes. Investment tax credits are deferred and amortized to income over the approximate lives of the related property.
MISO Transactions [Policy Text Block]	MISO Transactions. Indiana Electric is a member of MISO. MISO-related purchase and sale transactions are recorded using settlement information provided by the MISO. These purchase and sale transactions are accounted for on at least a net hourly position, meaning net purchases within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility natural gas, fuel and purchased power, and net sales within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility revenues. On occasion, prior period transactions are resettled outside the routine process due to a change in the MISO’s tariff or a material interpretation thereof. Expenses associated with resettlements are recorded once the resettlement is probable and the resettlement amount can be estimated. Revenues associated with resettlements are recognized when the amount is determinable and collectability is reasonably assured.

Disclosure of accounting policy for income taxes, which may include its accounting policies for recognizing and measuring deferred tax assets and liabilities and related valuation allowances, recognizing investment tax credits, operating loss carryforwards, tax credit carryforwards, and other carryforwards, methodologies for determining its effective income tax rate and the characterization of interest and penalties in the financial statements.

Schedule of Business Acquisitions, by Acquisition [Table Text Block]

Leases (Policies)	9 Months Ended
Leases (Policies)	Sep. 30, 2019
Leases [Abstract]
Lessee, Leases [Policy Text Block]	The Registrants adopted ASC 842, Leases, and all related amendments on January 1, 2019 using the modified retrospective transition method and elected not to recast comparative periods in the year of adoption as permitted by the standard. There was no adjustment to retained earnings as a result of transition. As a result, disclosures for periods prior to adoption will be presented in accordance with accounting standards in effect for those periods. The Registrants also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed them to carry forward the historical lease classification. Additionally, the Registrants elected the practical expedient related to land easements, which allows the carry forward of the accounting treatment for land easements on existing agreements. The total ROU assets obtained in exchange for new operating lease liabilities upon adoption were $30 million, $1 million and $27 million for CenterPoint Energy, Houston Electric and CERC, respectively. The Merger was completed on February 1, 2019, and as such the amounts recorded upon adoption are exclusive of Vectren’s leases. An arrangement is determined to be a lease at inception based on whether the Registrant has the right to control the use of an identified asset. ROU assets represent the Registrants’ right to use the underlying asset for the lease term and lease liabilities represent the Registrants’ obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Registrants are the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. Each Registrant uses the implicit rate for agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases. The Registrants have lease agreements with lease and non-lease components and have elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings. For classes of leases in which lease and non-lease components are not combined, consideration is allocated between components based on the stand-alone prices. Variable payments are not significant to the Registrants. The Registrants’ lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties. Agreements in which the Registrants are lessors do not include provisions for the lessee to purchase the assets. Because risk is minimal, the Registrants do not take any significant actions to manage risk associated with the residual value of their leased assets. The Registrants’ lease agreements are primarily equipment and real property leases, including land and office facility leases. The Registrants’ lease terms may include options to extend or terminate a lease when it is reasonably certain that those options will be exercised. Operating lease payments exclude approximately $16 million of legally-binding undiscounted minimum lease payments for leases signed but not yet commenced. The Registrants have elected an accounting policy that exempts leases with terms of one year or less from the recognition requirements of ASU 842.

Mergers and Acquisitions (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2019

Business Combinations [Abstract]

The following table presents the preliminary purchase price allocation as of September 30, 2019 (in millions):



Cash and cash equivalents	$	16
Other current assets	598
Property, plant and equipment, net	5,146
Identifiable intangibles	322
Regulatory assets	338
Other assets	151
Total assets acquired	6,571
Current liabilities	690
Regulatory liabilities	944
Other liabilities	860
Long-term debt	2,401
Total liabilities assumed	4,895
Net assets acquired	1,676
Goodwill	4,306
Total purchase price consideration	$	5,982

Schedule of Finite-Lived Intangible Assets Acquired as Part of Business Combination [Table Text Block]

The estimated fair value of the identifiable intangible assets and related useful lives as included in the preliminary purchase price allocation include:



	Weighted Average Useful Lives	Estimated Fair Value
	(in years)	(in millions)
Operation and maintenance agreements	24	$	12
Customer relationships	18	220
Construction backlog	1	28
Trade names	10	62
Total		$	322

Business Combination, Separately Recognized Transactions [Table Text Block]

The results of operations for Vectren included in CenterPoint Energy’s Interim Condensed Financial Statements from the Merger Date are as follows:



	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
	(in millions)
Operating revenues	$	756	$	1,917
Net income	67		86

Business Acquisition, Pro Forma Information [Table Text Block]



	Three Months Ended September 30,					Nine Months Ended September 30,
	2019		2018			2019			2018
	(in millions)
Operating revenues	$	2,742	$	2,877		$	9,317		$	9,521
Net income	279		212		(1)	649		(2)	282		(3)


(1)	Pro forma net income was adjusted to exclude $18 million of Vectren Merger-related transaction costs incurred in 2018 and reflected in the historical income statements.


(2)	Pro forma net income was adjusted to exclude $37 million of Vectren Merger-related transaction costs incurred in 2019.


(3)	Pro forma net income was adjusted to include $38 million and $1 million, respectively, of Vectren and CenterPoint Energy Merger-related transaction costs incurred from October 1, 2018 to September 30, 2019.

New Accounting Pronouncements (Tables)

9 Months Ended

Sep. 30, 2019

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Schedule of New Accounting Pronouncements and Changes in Accounting Principles [Table Text Block]

The following table provides an overview of certain recently adopted or issued accounting pronouncements applicable to all the Registrants, unless otherwise noted.



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Effective Date	Financial Statement Impact upon Adoption
ASU 2016-13- Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	This standard, including standards amending this standard, requires a new model called CECL to estimate credit losses for (1) financial assets subject to credit losses and measured at amortized cost and (2) certain off-balance sheet credit exposures. Upon initial recognition of the exposure, the CECL model requires an entity to estimate the credit losses expected over the life of an exposure based on historical information, current information and reasonable and supportable forecasts, including estimates of prepayments. Transition method: modified retrospective	January 1, 2020 Early adoption is permitted	The adoption of this standard may result in an adjustment to the carrying value of the Registrants’ accounts receivable. The Registrants do not anticipate the adoption of this standard will have a material impact on the Registrants’ financial position, results of operations or cash flows.
ASU 2018-13- Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement	This standard eliminates, modifies and adds certain disclosure requirements for fair value measurements. Transition method: prospective for additions and one modification and retrospective for all other amendments	Adoption of eliminations and modifications as of September 30, 2018; Additions will be adopted January 1, 2020	The adoption of this standard did not impact the Registrants’ financial position, results of operations or cash flows. Note 8 reflects the disclosures modified upon adoption.
ASU 2018-15- Intangibles-Goodwill and Other- Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns accounting for implementation costs incurred in a cloud computing arrangement that is accounted for as a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also prescribes the balance sheet, income statement, and cash flow classification of the capitalized implementation costs and related amortization expense and requires additional quantitative and qualitative disclosures. Transition method: retrospective or prospective	January 1, 2020 Early adoption is permitted	The adoption of this standard will require the Registrants to capitalize certain costs to implement cloud computing arrangements that are accounted for as service contracts within Prepaid expenses and other current assets on the Registrants’ condensed consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ condensed statements of consolidated income. The Registrants do not anticipate the adoption of this standard will have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures.

Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2019

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue [Table Text Block]

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

CenterPoint Energy



	Three Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	861		$	165	$	518		$	81		$	377		$	91	$	2,093
Derivatives income	—			—		—			664			—			—		664
Other (3)	(2		)	—		6			—			—			2		6
Eliminations	—			—		(9		)	(11		)	(1		)	—		(21		)
Total revenues	$	859		$	165	$	515		$	734		$	376		$	93	$	2,742

	Nine Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1) (4)		Natural Gas Distribution (1) (4)			Energy Services (2)			Infrastructure Services (2) (4)			Corporate and Other (2) (4)		Total
	(in millions)
Revenue from contracts	$	2,319		$	388	$	2,581		$	341		$	849		$	210	$	6,688
Derivatives income	3			—		—			2,505			—			—		2,508
Other (3)	(9		)	—		2			—			—			5		(2		)
Eliminations	—			—		(29		)	(92		)	(2		)	—		(123		)
Total revenues	$	2,313		$	388	$	2,554		$	2,754		$	847		$	215	$	9,071



	Three Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	904		$	—	$	398		$	82		$	—	$	1	$	1,385
Derivatives income	—			—		—			838			—		—		838
Other (3)	(7		)	—		12			—			—		2		7
Eliminations	—			—		(8		)	(10		)	—		—		(18		)
Total revenues	$	897		$	—	$	402		$	910		$	—	$	3	$	2,212

	Nine Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,525		$	—	$	2,093		$	338		$	—	$	4	$	4,960
Derivatives income	(4		)	—		—			2,727			—		—		2,723
Other (3)	(19		)	—		(35		)	—			—		7		(47		)
Eliminations	—			—		(26		)	(57		)	—		—		(83		)
Total revenues	$	2,502		$	—	$	2,032		$	3,008		$	—	$	11	$	7,553


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)


(4)	Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to September 30, 2019.

Houston Electric



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)
Revenue from contracts	$	861		$	904		$	2,319		$	2,525
Other (1)	(2		)	(7		)	(9		)	(19		)
Total revenues	$	859		$	897		$	2,310		$	2,506

(1)

CERC



	Three Months Ended September 30,
	2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	393		$	81		$	3	$	477		$	398		$	82		$	—	$	480
Derivatives income	—			664			—		664			—			838			—		838
Other (3)	5			—			—		5			12			—			—		12
Eliminations	(9		)	(11		)	—		(20		)	(8		)	(10		)	—		(18		)
Total revenues	$	389		$	734		$	3	$	1,126		$	402		$	910		$	—	$	1,312

	Nine Months Ended September 30,
	2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,101		$	341		$	4	$	2,446		$	2,093		$	338		$	—	$	2,431
Derivatives income	—			2,505			—		2,505			—			2,727			—		2,727
Other (3)	5			—			—		5			(35		)	—			—		(35		)
Eliminations	(29		)	(91		)	—		(120		)	(26		)	(57		)	—		(83		)
Total revenues	$	2,077		$	2,755		$	4	$	4,836		$	2,032		$	3,008		$	—	$	5,040


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)

Contract with Customer, Asset and Liability [Table Text Block]

CenterPoint Energy



	Accounts Receivable		Other Accrued Unbilled Revenues			Contract Assets		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2018 (1)	$	763	$	575		$	37	$	47
Closing balance as of September 30, 2019	779		403			75		42
Increase (decrease)	$	16	$	(172	)	$	38	$	(5	)


(1)	Opening balances related to Vectren are as of February 1, 2019.

Houston Electric



	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Liabilities
	(in millions)
Opening balance as of December 31, 2018	$	234	$	110	$	3
Closing balance as of September 30, 2019	325		136		4
Increase	$	91	$	26	$	1

CERC



	Accounts Receivable			Other Accrued Unbilled Revenues
	(in millions)
Opening balance as of December 31, 2018	$	282		$	263
Closing balance as of September 30, 2019	137			82
Decrease	$	(145	)	$	(181	)

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

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]



	Rolling 12 Months		Thereafter		Total
	(in millions)
Revenue expected to be recognized on contracts in place as of September 30, 2019:
Fixed price (bid)	$	365	$	—	$	365
	$	365	$	—	$	365

Employee Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2019

Retirement Benefits [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

Pension Benefits (CenterPoint Energy)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)
Service cost (1)	$	10		$	10		$	30		$	28
Interest cost (2)	25			20			73			59
Expected return on plan assets (2)	(27		)	(27		)	(79		)	(80		)
Amortization of prior service cost (2)	2			3			6			7
Amortization of net loss (2)	13			10			39			32
Settlement cost (3) (2)	1			—			2			—
Curtailment gain (4) (2)	—			—			(1		)	—
Net periodic cost	$	24		$	16		$	70		$	46


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


(3)	A one-time, non-cash settlement cost is 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. CenterPoint Energy recognized a non-cash settlement cost of $1 million in June and September 2019, respectively, due to lump sum settlement payments.


(4)	A curtailment gain or loss is required when the expected future services of a significant number of employees are reduced or eliminated for the accrual of benefits. In February 2019, CenterPoint Energy recognized a pension curtailment gain of $1 million related to Vectren employees whose employment was terminated after the Merger closed.

Postretirement Benefits



	Three Months Ended September 30,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	2		$	—		$	—		$	—		$	—		$	1
Interest cost (2)	4			1			2			3			2			1
Expected return on plan assets (2)	(3		)	(1		)	—			(1		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(1		)	—			(1		)	(1		)	—
Net periodic cost (income)	$	2		$	(1	)	$	2		$	1		$	—		$	2

	Nine Months Ended September 30,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	3		$	—		$	1		$	1		$	—		$	1
Interest cost (2)	12			5			4			10			6			3
Expected return on plan assets (2)	(6		)	(3		)	(1		)	(4		)	(3		)	(1		)
Amortization of prior service cost (credit) (2)	(3		)	(4		)	—			(3		)	(4		)	1
Net periodic cost (income)	$	6		$	(2	)	$	4		$	4		$	(1	)	$	4


(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.

Benefit Plan Contributions [Table Text Block]

The table below reflects the expected contributions to be made to the pension and postretirement benefit plans during 2019:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2019	$	94	$	—	$	—
Expected contribution to postretirement benefit plans in 2019	20		10		4

The table below reflects the contributions made to the pension and postretirement benefit plans during 2019:



	Three Months Ended September 30, 2019						Nine Months Ended September 30, 2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	65	$	—	$	—	$	94	$	—	$	—
Postretirement benefit plans	4		3		1		12		8		3

Regulatory Matters (Tables)

9 Months Ended

Sep. 30, 2019

Regulatory Assets and Liabilities, Other Disclosures [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

The following is a list of regulatory assets and liabilities reflected on the Registrants’ respective Condensed Consolidated Balance Sheets:



	September 30, 2019									December 31, 2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	18		$	—		$	18		$	77		$	—		$	77
Non-current regulatory assets:
Securitized regulatory assets	821			821			—			1,059			1,059			—
Unrecognized equity return (2)	(175		)	(175		)	—			(213		)	(213		)	—
Unamortized loss on reacquired debt (3)	63			63			—			68			68			—
Pension and postretirement-related regulatory asset (3)	683			35			27			725			33			30
Hurricane Harvey restoration costs (3)	68			64			4			68			64			4
Regulatory assets related to TCJA (3) (4)	30			23			7			33			23			10
Asset retirement obligation (3)	139			25			92			109			24			85
Other regulatory assets-not earning a return (5)	154			65			46			81			55			26
Other regulatory assets	411			30			13			37			11			26
Total non-current regulatory assets	2,194			951			189			1,967			1,124			181
Total regulatory assets	2,212			951			207			2,044			1,124			258
Regulatory Liabilities:
Current regulatory liabilities (6)	31			—			28			38			17			21
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	1,606			830			449			1,323			847			476
Estimated removal costs	1,430			259			634			886			269			617
Other regulatory liabilities	445			206			138			316			182			134
Total non-current regulatory liabilities	3,481			1,295			1,221			2,525			1,298			1,227
Total regulatory liabilities	3,512			1,295			1,249			2,563			1,315			1,248
Total regulatory assets and liabilities, net	$	(1,300	)	$	(344	)	$	(1,042	)	$	(519	)	$	(191	)	$	(990	)


(1)	Current regulatory assets are included in Prepaid expenses and other current assets in the Registrants’ respective Condensed Consolidated Balance Sheets.

(2)



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Allowed equity return recognized	$	14	$	14	$	17	$	17	$	38	$	38	$	62	$	62


(3)	Substantially all of these regulatory assets are not earning a return.


(4)	The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities.


(5)	Regulatory assets acquired in the Merger and not earning a return were recorded at fair value as of the Merger Date. Such fair value adjustments are recognized over time until the regulatory asset is recovered.

(6)

Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Condensed Consolidated Balance Sheets.

Amount_Allowed_equity_return_recognized_in_period [Table Text Block]



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Allowed equity return recognized	$	14	$	14	$	17	$	17	$	38	$	38	$	62	$	62

Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]

The table below summarizes the Registrants’ outstanding interest rate hedging activity:



	September 30, 2019				December 31, 2018
Hedging Classification	Notional Principal
	CenterPoint Energy (1)		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Economic hedge	$	84	$	—	$	—	$	—
Cash flow hedge	—		—		450		450

(1)

Relates to interest rate derivative instruments at SIGECO.

Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]

The tables below summarize CenterPoint Energy’s and CERC’s current weather hedge gain (loss) activity:



	Three Months Ended September 30,
	2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC
	(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—	$	—
Electric operations	2018 – 2019	8		—		—		2017 – 2018	9		—		—
Total (1)				$	—	$	—				$	—	$	—



	Nine Months Ended September 30,
	2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy			CERC
	(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—		$	—
Electric operations	2018 – 2019	8		3		—		2017 – 2018	9		(4		)	—
Total (1)				$	3	$	—				$	(4	)	$	—

(1)

Weather hedge gains (losses) are recorded in Revenues in the Condensed Statements of Consolidated Income.

Fair Value of Derivative Instruments [Table Text Block]

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as cash flow hedges:
Interest rate derivatives	Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	7		—		1		7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	69		154		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	13		68		16		25
Interest rate derivatives	Other Liabilities	—		15		—		—
Indexed debt securities derivative	Current Liabilities	—		817		—		601
Total CenterPoint Energy		$	277	$	1,057	$	220	$	833


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)


(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

Houston Electric



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as cash flow hedges:
Interest rate derivatives	Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Total Houston Electric		$	—	$	—	$	—	$	24

CERC



		September 30, 2019				December 31, 2018
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	$	7	$	—	$	1	$	7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	69		148		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	13		54		16		25
Total CERC		$	277	$	205	$	220	$	208


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)


(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

Cumulative Basis Adjustment for Fair Value Hedges (CenterPoint Energy and CERC)



		September 30, 2019
	Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		CenterPoint Energy		CERC		CenterPoint Energy			CERC
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	42	$	42	$	(7	)	$	(7	)
Total		$	42	$	42	$	(7	)	$	(7	)



		December 31, 2018
	Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		CenterPoint Energy		CERC		CenterPoint Energy		CERC
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	57	$	57	$	1	$	1
Total		$	57	$	57	$	1	$	1

Offsetting of Natural Gas Derivative Assets and Liabilities [Table Text Block]

Offsetting of Natural Gas Derivative Assets and Liabilities (CenterPoint Energy and CERC)

CenterPoint Energy



	September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)
Current Assets: Non-trading derivative assets	$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(157		)	107			(50		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(68		)	36			(32		)	(25		)	20			(5		)
Total CenterPoint Energy	$	52		$	50		$	102		$	12		$	19		$	31

CERC



	September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)
Current Assets: Non-trading derivative assets	$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(151		)	107			(44		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(54		)	36			(18		)	(25		)	20			(5		)
Total CERC	$	72		$	50		$	122		$	12		$	19		$	31


(1)	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.


(2)	The derivative assets and liabilities on the Registrant’s respective Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

Income Statement Impact of Derivative Activity [Table Text Block]

Income Statement Impact of Hedge Accounting Activity (CenterPoint Energy and CERC)



	Three Months Ended September 30,
	2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	852		$	687		$	864		$	864
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	2			2			1			1
Derivatives designated as hedging instruments	(2		)	(2		)	(1		)	(1		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(59		)	(59		)	6			6



	Nine Months Ended September 30,
	2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	3,013		$	2,627		$	2,927		$	2,927
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(8		)	(8		)	(13		)	(13		)
Derivatives designated as hedging instruments	8			8			13			13
Amounts excluded from effectiveness testing recognized in earnings immediately	(138		)	(138		)	(73		)	(73		)


(1)	Income statement impact associated with cash flow hedge activity is related to gains and losses reclassified from Accumulated other comprehensive income into income. Amounts are immaterial for each Registrant in the three and nine months ended September 30, 2019 and 2018, respectively.

CenterPoint Energy



		Three Months Ended September 30,						Nine Months Ended September 30,
	Income Statement Location	2019			2018			2019			2018
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (losses) in Non-utility revenues	$	69		$	2		$	159		$	70
Indexed debt securities derivative	Loss on indexed debt securities	(62		)	(44		)	(216		)	(316		)
Total CenterPoint Energy		$	7		$	(42	)	$	(57	)	$	(246	)

CERC



		Three Months Ended September 30,				Nine Months Ended September 30,
	Income Statement Location	2019		2018		2019		2018
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (losses) in Non-utility revenues	$	69	$	2	$	159	$	70
Total CERC		$	69	$	2	$	159	$	70

Disclosure of Credit Derivatives [Table Text Block]



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position	$	1	$	1	$	1	$	1
Fair value of collateral already posted	—		—		—		—
Additional collateral required to be posted if credit risk contingent features triggered	1		1		—		—

Tabular disclosure of credit derivatives which includes information by sellers of credit derivatives, about each credit derivative, or each group of similar credit derivatives, including (a) the nature of the credit derivative - its term, how it arose, the events or circumstances that would require the seller to perform under the credit derivative, and the current status of the payment/performance risk of the credit derivative; (b) the maximum potential amount of future payments (undiscounted) the seller could be required to make under the credit derivative; (c) the current fair value of the credit derivative; and (d) the nature of any recourse provisions under the credit derivative, and any assets held either as collateral or by third parties. A credit derivative is a derivative instrument (1) in which one or more of its underlyings are related to the credit risk of a specified entity (or a group of entities) or an index based on the credit risk of a group of entities and (2) that exposes the seller to potential loss from credit-risk-related events specified in the contract. Examples of credit derivatives within the scope of this paragraph include, but are not limited to, credit default swaps, credit spread options, and credit index products; also includes a hybrid instrument that has an embedded credit derivative (for example, but not limited to, a credit-linked note).

Fair value, assets and liabilities measured on a recurring basis [Table Text Block]

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

CenterPoint Energy



	September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	748	$	—	$	—	$	—		$	748	$	542	$	—	$	—	$	—		$	542
Investments, including money market funds (2)	50		—		—		—			50		66		—		—		—			66
Natural gas derivatives (3)(4)	—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	798	$	234	$	43	$	(93	)	$	982	$	609	$	173	$	47	$	(82	)	$	747
Liabilities
Indexed debt securities derivative	$	—	$	817	$	—	$	—		$	817	$	—	$	601	$	—	$	—		$	601
Interest rate derivatives	—		15		—		—			15		24		—		—		—			24
Natural gas derivatives (3)(4)	—		203		22		(143		)	82		—		191		17		(101		)	107
Hedged portion of natural gas inventory	7		—		—		—			7		—		—		—		—			—
Total liabilities	$	7	$	1,035	$	22	$	(143	)	$	921	$	24	$	792	$	17	$	(101	)	$	732

Houston Electric



	September 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Netting		Total		Level 1		Level 2		Level 3		Netting		Total
Assets	(in millions)
Investments, including money market funds (2)	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Total assets	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Liabilities
Interest rate derivatives	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24

CERC



	September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	2	$	—	$	—	$	—		$	2	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)(4)	—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	13	$	234	$	43	$	(93	)	$	197	$	14	$	173	$	47	$	(82	)	$	152
Liabilities
Natural gas derivatives (3)(4)	$	—	$	183	$	22	$	(143	)	$	62	$	—	$	191	$	17	$	(101	)	$	107
Hedged portion of natural gas inventory	7		—		—		—			7		—		—		—		—			—
Total liabilities	$	7	$	183	$	22	$	(143	)	$	69	$	—	$	191	$	17	$	(101	)	$	107


(1)	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy and CERC to settle positive and negative positions and also include cash collateral posted with the same counterparties as follows:



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	50	$	50	$	19	$	19


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


(3)	Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

(4)

Assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs [Table Text Block]



	Three Months Ended September 30,												Nine Months Ended September 30,
	2019						2018						2019						2018
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	20		$	20		$	(628	)	$	13		$	30		$	30		$	(622	)	$	46
Total gains	4			4			1			1			16			16			4			4
Total settlements	(1		)	(1		)	(1		)	(1		)	(18		)	(18		)	(36		)	(36		)
Transfers into Level 3	—			—			—			—			(1		)	(1		)	(2		)	(2		)
Transfers out of Level 3	(2		)	(2		)	650			9			(6		)	(6		)	678			10
Ending balance (1)	$	21		$	21		$	22		$	22		$	21		$	21		$	22		$	22

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:
	$	2		$	2		$	11		$	11		$	13		$	13		$	9		$	9


(1)	CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during the three or nine months ended September 30, 2019 or 2018.

Estimated fair value of financial instruments, debt instruments [Table Text Block]



	September 30, 2019				December 31, 2018
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
CenterPoint Energy
Long-term debt, including current maturities (1)	$	14,861	$	15,994	$	9,140	$	9,308
Houston Electric
Long-term debt, including current maturities (1)	$	5,018	$	5,595	$	4,717	$	4,770
CERC
Long-term debt, including current maturities	$	2,477	$	2,783	$	2,371	$	2,488

(1)

Includes Securitization Bonds debt.

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Tables)

9 Months Ended

Sep. 30, 2019

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Investment in Unconsolidated Affiliates (CenterPoint Energy):



	September 30, 2019		December 31, 2018
	(in millions)
Enable	$	2,467	$	2,482
Other (1)	2		—
Total	$	2,469	$	2,482

(1)

Represents the equity investment in ProLiance Holdings, LLC related primarily to an investment in LA Storage, LLC, a joint venture in a development project for salt-cavern natural gas storage, which was acquired in the Merger. This presentation reflects preliminary fair value of the equity investment on the acquisition date and is subject to change. See Note 3.

Limited Partner Interest and Units Held in Enable (CenterPoint Energy):



	September 30, 2019
	Limited Partner Interest (1)		Common Units (2)	Enable Series A Preferred Units (3)
CenterPoint Energy	53.7	%	233,856,623	14,520,000
OGE	25.5	%	110,982,805	—
Public unitholders	20.8	%	90,310,731	—
Total units outstanding	100.0	%	435,150,159	14,520,000


(1)	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.


(2)	Held indirectly through CNP Midstream by CenterPoint Energy.

(3)

The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of September 30, 2019 and $363 million as of December 31, 2018. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods.

Interests Held in Enable GP (CenterPoint Energy):



	September 30, 2019
	Management Rights (1)		Incentive Distribution Rights (2)
CenterPoint Energy (3)	50	%	40	%
OGE	50	%	60	%


(1)	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.

(2)


(3)	Held indirectly through CNP Midstream.

Distributions Received from Enable (CenterPoint Energy and CERC):

CenterPoint Energy



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.3305	$	77	$	0.3180	$	74	$	0.9665	$	226	$	0.9540	$	223
Enable Series A Preferred Units	0.6250		9		0.6250		9		1.8750		27		1.8750		27
Total CenterPoint Energy			$	86			$	83			$	253			$	250

CERC



	Three Months Ended September 30, 2018				Nine Months Ended September 30, 2018
	Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.3180	$	74	$	0.9540	$	223
Total CERC			$	74			$	223


(1)	Prior to the Internal Spin in September 2018, distributions from Enable were received by CERC. After such date, distributions from Enable were received by CenterPoint Energy.

Transactions with Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
CenterPoint Energy
Natural gas expenses, including transportation and storage costs (1)	$	26	$	23	$	89	$	89
Reimbursement of support services (2)	—		1		3		4
CERC
Natural gas expenses, including transportation and storage costs (1)	26		23		89		89
Reimbursement of support services (2)	—		1		3		4


(1)	Included in Non-utility costs of revenues, including natural gas on CenterPoint Energy’s and CERC’s respective Condensed Statements of Consolidated Income.


(2)	Represents amounts billed for certain support services provided to Enable. Actual support services costs are recorded net of reimbursement.



	September 30, 2019		December 31, 2018
	(in millions)
CenterPoint Energy
Accounts payable for natural gas purchases from Enable	$	9	$	11
Accounts receivable for amounts billed for services provided to Enable	3		2
CERC
Accounts payable for natural gas purchases from Enable	9		11
Accounts receivable for amounts billed for services provided to Enable	3		2

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019			2018
	(in millions)
Operating revenues	$	699	$	928	$	2,229		$	2,481
Cost of sales, excluding depreciation and amortization	263		516		958			1,335
Depreciation and amortization	108		100		323			292
Operating income	175		171		507			436
Net income attributable to Enable common units	123		129		351			320
Reconciliation of Equity in Earnings (Losses), net:
CenterPoint Energy’s interest	$	66	$	70	$	189		$	173
Basis difference amortization (1)	11		11		35			35
Loss on dilution, net of proportional basis difference recognition	—		—		(11		)	—
CenterPoint Energy’s equity in earnings, net	$	77	$	81	$	213		$	208


(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 original investment in Enable and its underlying equity in net assets of Enable. The basis difference is being amortized through the year 2048.

Summarized unaudited consolidated balance sheet information for Enable is as follows:



	September 30, 2019			December 31, 2018
	(in millions)
Current assets	$	417		$	449
Non-current assets	12,018			11,995
Current liabilities	819			1,615
Non-current liabilities	4,076			3,211
Non-controlling interest	37			38
Preferred equity	362			362
Accumulated other comprehensive loss	(4		)	—
Enable partners’ equity	7,145			7,218
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,838		$	3,896
CenterPoint Energy’s basis difference	(1,371		)	(1,414		)
CenterPoint Energy’s equity method investment in Enable	$	2,467		$	2,482

Discontinued Operations (CERC) [Table Text Block]



		Three months ended September 30, 2018		Nine months ended September 30, 2018
	(in millions)
Equity in earnings of unconsolidated affiliate, net		$	57	$	184
Income tax expense		13		44
Income from discontinued operations, net of tax		$	44	$	140

Goodwill and Intangible Assets Disclosure [Abstract]

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

+ References

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Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 13: http://fasb.org/us-gaap/role/ref/legacyRef
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+ Details

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

9 Months Ended

Sep. 30, 2019

Schedule of Goodwill [Table Text Block]

CenterPoint Energy’s goodwill by reportable segment as of December 31, 2018 and changes in the carrying amount of goodwill as of September 30, 2019 is as follows:



	December 31, 2018		Additions (1)		September 30, 2019
	(in millions)
Indiana Electric Integrated	$	—	$	1,008	$	1,008
Natural Gas Distribution	746		2,529		3,275
Energy Services (2)	110		—		110
Infrastructure Services	—		355		355
Corporate and Other	11		420		431
Total	$	867	$	4,312	$	5,179


(1)	The allocation of goodwill to reportable segments subsequent to the Merger is preliminary and subject to change. See Note 3.


(2)	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

CERC’s goodwill by reportable segment as of September 30, 2019 and December 31, 2018 is as follows:



	September 30, 2019		December 31, 2018
	(in millions)
Natural Gas Distribution	$	746	$	746
Energy Services (1)	110		110
Corporate and Other	11		11
Total	$	867	$	867

(1)

Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

Schedule of Finite-Lived Intangible Assets [Table Text Block]



	September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships	$	86	$	(31	)	$	55	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1
Other	16		(14		)	2		16		(11		)	5
Total	$	106	$	(48	)	$	58	$	106	$	(41	)	$	65



	September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships (1)	$	306	$	(40	)	$	266	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1
Trade names (1)	62		(4		)	58		—		—			—
Construction backlog (1) (2)	28		(18		)	10		—		—			—
Operation and maintenance agreements (1) (2)	12		(1		)	11		—		—			—
Other (1)	24		(14		)	10		16		(11		)	5
Total	$	436	$	(80	)	$	356	$	106	$	(41	)	$	65


(1)	The fair value of intangible assets acquired through acquisitions is preliminary and subject to change. See Note 3.

(2)

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

Finite-lived Intangible Assets Amortization Expense [Table Text Block]



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	2	$	2	$	7	$	7



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization (1)	$	7	$	2	$	20	$	7
Amortization expense of intangible assets recorded in Non-utility cost of revenues, including natural gas (2)	7		—		19		—


(1)	Includes $5 million and $13 million for the three and nine months ended September 30, 2019, respectively, of amortization expense related to intangibles acquired in the Merger. The fair value of intangible assets, and related amortization

assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.

(2)

The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]

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



	Amortization Expense
	CenterPoint Energy		CERC
	(in millions)
Remaining three months of 2019	$	15	$	4
2020	32		6
2021	31		6
2022	32		6
2023	31		5
2024	29		5

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2019

Investments, Debt and Equity Securities [Abstract]

Schedule of Indexed Debt Securities and Marketable Securities [Table Text Block]



	Shares Held
	September 30, 2019	December 31, 2018
AT&T Common	10,212,945	10,212,945
Charter Common	872,503	872,912



	September 30, 2019	December 31, 2018
	(in shares)
AT&T Common	0.7185	0.7185
Charter Common	0.061382	0.061382

Short-Term Borrowings and Long-term Debt (Tables)

9 Months Ended

Sep. 30, 2019

Debt Disclosure [Abstract]

Schedule of Debt [Table Text Block]


(b)	Long-term Debt

Debt Transactions. During the nine months ended September 30, 2019, the following debt instruments were issued or incurred:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of September 30, 2019		Maturity Date
			(in millions)
Houston Electric	January 2019	General mortgage bonds	$	700	4.25	%	2049
CenterPoint Energy (1)	February 2019	Variable rate term loan	25		2.88	%	2020
CenterPoint Energy	May 2019	Variable rate term loan	1,000		2.81	%	2021
CenterPoint Energy	August 2019	Unsecured senior notes	500		2.50	%	2024
CenterPoint Energy	August 2019	Unsecured senior notes	400		2.95	%	2030
CenterPoint Energy	August 2019	Unsecured senior notes	300		3.70	%	2049


(1)	Draw down by VCC on its variable rate term loan.

Acquired Debt (CenterPoint Energy). The table below summarizes the long-term external debt of Vectren and its subsidiaries that remained outstanding as of September 30, 2019:



	(in millions)
Long-term debt:
Senior notes due 2020 to 2045 (1)	$	637
Variable rate term loan due 2020 (2)	300
Variable rate term loan due 2020 (3)	200
First mortgage bonds due 2022 to 2055 (4)	293
Commercial paper (5)	278
Bank revolver (6)	—
Total Vectren debt	$	1,708

(1)


(2)	Issued by VUHI and guaranteed by SIGECO, Indiana Gas and VEDO. As of September 30, 2019, the term loan was fully drawn upon. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread ranging from 70 to 90 basis points depending on credit rating.


(3)	Issued by VCC and guaranteed by Vectren. As of September 30, 2019, the term loan was fully drawn upon, exclusive of any potential incremental term loans under the related facility’s accordion feature. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread of 70 basis points.


(4)	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture. The first mortgage bonds have stated interest rates that range from 2.375% to 6.72%.


(5)	Issued by VUHI with maturities up to 30 days.

(6)

Represents borrowings under the VCC credit facility, which is guaranteed by Vectren.

Schedule of Maturities of Long-term Debt [Table Text Block]

Maturities (CenterPoint Energy). As of September 30, 2019, maturities of CenterPoint Energy’s long-term debt were as follows:



	(in millions)
Remaining three months of 2019	$	69
2020	831
2021	2,761
2022	2,998
2023	713
2024	1,184
2025 and thereafter	6,447

Schedule of Line of Credit Facilities [Table Text Block]

Credit Facilities. The Registrants had the following revolving credit facilities as of September 30, 2019:



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, 2019 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	3,300	1.500%	65%	(3)	58.6%	March 3, 2022
July 14, 2017	CenterPoint Energy (4)	400		1.125%	65%		52.9%	July 14, 2022
July 14, 2017	CenterPoint Energy (5)	200		1.250%	65%		57.1%	July 14, 2022
March 3, 2016	Houston Electric	300		1.125%	65%	(3)	48.7%	March 3, 2022
March 3, 2016	CERC	900		1.250%	65%		47.5%	March 3, 2022
	Total	$	5,100


(1)	Based on current credit ratings.


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

(3)


(4)	This credit facility was issued by VUHI, is guaranteed by SIGECO, Indiana Gas and VEDO and includes a $10 million swing line sublimit and a $20 million letter of credit sublimit. This credit facility backstops VUHI’s commercial paper program.


(5)	This credit facility was issued by VCC, is guaranteed by Vectren and includes a $40 million swing line sublimit and an $80 million letter of credit sublimit.

The Registrants, including the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of September 30, 2019.

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



	September 30, 2019								December 31, 2018
Registrant	Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate
	(in millions, except weighted average interest rate)
CenterPoint Energy (1)	$	—	$	6	$	1,383	2.28	%	$	—	$	6	$	—	—	%
CenterPoint Energy (2)	—		—		278		2.30	%	—		—		—		—
CenterPoint Energy (3)	—		—		—		—	%	—		—		—		—
Houston Electric	—		—		—		—	%	—		4		—		—
CERC	—		1		310		2.28	%	—		1		210		2.93	%
Total	$	—	$	7	$	1,971			$	—	$	11	$	210


(1)	CenterPoint Energy’s outstanding commercial paper generally has maturities of 60 days or less.


(2)	This credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.


(3)	This credit facility was issued by VCC and is guaranteed by Vectren.

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

The Registrants reported the following effective tax rates:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
CenterPoint Energy (1)	19	%	24	%	15	%	26	%
Houston Electric (2)	18	%	20	%	18	%	21	%
CERC - Continuing operations (3) (4)	13	%	5	%	14	%	29	%
CERC - Discontinued operations (5)	n/a		23	%	n/a		24	%

(1)


(2)	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2019 compared to the same periods for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability.

(3)


(4)	CERC’s lower effective tax rate on income from continuing operations for the nine months ended September 30, 2019 compared to the same period for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the impact of changes in the valuation allowances on certain state net operating losses in 2019.


(5)	CERC’s effective tax rate on income from discontinued operations for the three and nine months ended September 30, 2018 was a result of the 21% federal income tax rate plus allocable state income taxes. There are no comparable periods in 2019 since the Internal Spin was completed in the third quarter of 2018.

Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment [Table Text Block]

As of September 30, 2019, minimum purchase obligations are approximately:



	CenterPoint Energy		CERC
	(in millions)
Remaining three months of 2019	$	217	$	160
2020	745		528
2021	614		429
2022	412		235
2023	330		177
2024	265		169
2025 and beyond	1,846		1,483

Schedule of Environmental Loss Contingencies by Site [Table Text Block]


(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)


(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.



	September 30, 2019
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	9	$	7
Minimum estimated remediation costs	7		4
Maximum estimated remediation costs	51		32
Minimum years of remediation	5		30
Maximum years of remediation	50		50

Earnings Per Share (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2019

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions, except share and per share amounts)
Numerator:
Income available to common shareholders - basic	$	241	$	153	$	546	$	243
Add back: Series B Preferred Stock dividend	—		—		—		—
Income available to common shareholders - diluted	$	241	$	153	$	546	$	243

Denominator:
Weighted average common shares outstanding - basic	502,228,000		431,554,000		501,986,000		431,437,000
Plus: Incremental shares from assumed conversions:
Restricted stock	2,852,000		3,337,000		2,852,000		3,337,000
Series B Preferred Stock (1)	—		—		—		—
Weighted average common shares outstanding - diluted	505,080,000		434,891,000		504,838,000		434,774,000

Earnings per common share:
Basic earnings per common share	$	0.48	$	0.35	$	1.09	$	0.56
Diluted earnings per common share	$	0.47	$	0.35	$	1.08	$	0.56

(1)

Reportable Business Segments (Tables)

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

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

Financial data for reportable segments is as follows:

CenterPoint Energy



	Three Months Ended September 30,
	2019								2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Houston Electric T&D	$	859	(1)	$	—		$	269	$	897	(1)	$	—		$	227
Indiana Electric Integrated	165			—			48		—			—			—
Natural Gas Distribution	515			9			27		402			8			3
Energy Services	734			11			2		910			10			(9		)
Infrastructure Services	376			1			42		—			—			—
Midstream Investments (2)	—			—			—		—			—			—
Corporate and Other	93			—			4		3			—			5
Eliminations	—			(21		)	—		—			(18		)	—
Consolidated	$	2,742		$	—		$	392	$	2,212		$	—		$	226



	Nine Months Ended September 30,
	2019									2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Houston Electric T&D	$	2,313	(1)	$	—		$	522		$	2,502	(1)	$	—		$	523
Indiana Electric Integrated	388			—			64			—			—			—
Natural Gas Distribution	2,554			29			241			2,032			26			166
Energy Services	2,754			92			64			3,008			57			(20		)
Infrastructure Services	847			2			50			—			—			—
Midstream Investments (2)	—			—			—			—			—			—
Corporate and Other	215			—			(17		)	11			—			(5		)
Eliminations	—			(123		)	—			—			(83		)	—
Consolidated	$	9,071		$	—		$	924		$	7,553		$	—		$	664


(1)	Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192


(2)	CenterPoint Energy’s Midstream Investments’ equity in earnings, net are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Enable	$	77	$	81	$	213	$	208

Houston Electric

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

included.


(1)	Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192

CERC



	Three Months Ended September 30,
	2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	389	$	9		$	20	$	402	$	8		$	3
Energy Services	734		11			2		910		10			(9		)
Other Operations	3		—			1		—		—			(1		)
Eliminations	—		(20		)	—		—		(18		)	—
Consolidated	$	1,126	$	—		$	23	$	1,312	$	—		$	(7	)



	Nine Months Ended September 30,
	2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	2,077	$	29		$	212	$	2,032	$	26		$	166
Energy Services	2,755		91			64		3,008		57			(20		)
Corporate and Other	4		—			1		—		—			—
Eliminations	—		(120		)	—		—		(83		)	—
Consolidated	$	4,836	$	—		$	277	$	5,040	$	—		$	146

CenterPoint Energy and CERC



	Total Assets
	September 30, 2019							December 31, 2018
	CenterPoint Energy				CERC			CenterPoint Energy				CERC
	(in millions)
Houston Electric T&D	$	11,463			$	—		$	10,509			$	—
Indiana Electric Integrated (1)	3,009				—			—				—
Natural Gas Distribution (1)	13,235				7,018			6,956				6,956
Energy Services	1,264				1,264			1,558				1,558
Infrastructure Services (1)	1,284				—			—				—
Midstream Investments	2,529				—			2,482				—
Corporate and Other (1)	4,884			(2)	121			6,156			(2)	66
Eliminations	(3,026		)		(474		)	(652		)		(366		)
Consolidated	$	34,642			$	7,929		$	27,009			$	8,214


(1)	Total assets by reportable segment include assets acquired in the Merger, which are based on preliminary fair value estimates and allocations on the acquisition date and are subject to change. See Note 3.

(2)

Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block]

Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192

Midstream Investments [Table Text Block]

CenterPoint Energy’s Midstream Investments’ equity in earnings, net are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Enable	$	77	$	81	$	213	$	208

Supplemental Disclosure of Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2019

Supplemental Cash Flow Elements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]

The table below provides supplemental disclosure of cash flow information:



	Nine Months Ended September 30,
	2019						2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	364	$	203	$	88	$	301	$	173	$	85
Income taxes, net	174		93		3		89		122		3
Non-cash transactions:
Accounts payable related to capital expenditures	178		91		75		140		87		66
Capital distribution associated with the Internal Spin	—		—		—		—		—		1,460
ROU assets obtained in exchange for lease liabilities (1)	43		1		28		—		—		—


(1)	Includes the transition impact of adoption of ASU 2016-02 Leases.



	September 30, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash and cash equivalents	$	259	$	228	$	2	$	4,231	$	335	$	14
Restricted cash included in Prepaid expenses and other current assets	38		19		—		46		34		11
Restricted cash included in Other	—		—		—		1		1		—
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	297	$	247	$	2	$	4,278	$	370	$	25

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

9 Months Ended

Sep. 30, 2019

Schedule of Money Pool Investment and Borrowing [Table Text Block]

The table below summarizes money pool activity:



	September 30, 2019						December 31, 2018
	Houston Electric			CERC			Houston Electric			CERC
	(in millions, except interest rates)
Money pool investments (borrowings) (1)	$	772		$	87		$	(1	)	$	114
Weighted average interest rate	2.32		%	2.32		%	2.42		%	2.42		%

(1)

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

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,
	2019					2018					2019					2018
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	38		$	31	$	47		$	36	$	132		$	106	$	138		$	105
Net affiliate service charges (billings)	(3		)	3		(3		)	3		(7		)	7		(8		)	8

The table below presents transactions among Houston Electric, CERC and their parent, Utility Holding.



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	60	$	16	$	60	$	75	$	100	$	119	$	123	$	286
Cash contribution from parent	—		—		—		600		590		—		—		600
Capital distribution to parent associated with the Internal Spin	—		—		—		1,460		—		—		—		1,460

Houston Electric and CERC affiliate related net interest income (expense) were as follows:



	Three Months Ended September 30,									Nine Months Ended September 30,
	2019				2018					2019				2018
	Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Interest income (expense) (1)	$	5	$	1	$	1	$	(2	)	$	14	$	3	$	1	$	(4	)


(1)	Interest income is included in Other income (expense), net and interest expense is included in Interest and other finance charges on Houston Electric’s and CERC’s respective Condensed Statements of Consolidated Income.

Leases (Tables)

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Lease, Cost [Table Text Block]

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,						Nine Months Ended September 30,
	2019						2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	8	$	—	$	1	$	19	$	—	$	4
Short-term lease cost	23		7		—		46		12		—
Variable lease cost	1		—		—		1		—		—
Total lease cost	$	32	$	7	$	1	$	66	$	12	$	4

Supplemental Balance Sheet Information Related To Leases [Table Text Block]

Supplemental balance sheet information related to leases was as follows:



	September 30, 2019
	CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	67		$	1		$	25
Total leased assets	$	67		$	1		$	25
Liabilities:
Current operating lease liability (2)	$	21		$	—		$	4
Non-current operating lease liability (3)	46			1			21
Total leased liabilities	$	67		$	1		$	25

Weighted-average remaining lease term (in years) - operating leases	5.2			5.4			7.9
Weighted-average discount rate - operating leases	3.41		%	3.51		%	3.66		%


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


(2)	Reported within Current other liabilities in the Condensed Consolidated Balance Sheets.

(3)

Reported within Other liabilities in the Condensed Consolidated Balance Sheets.

Lessee, Operating Lease, Liability, Maturity [Table Text Block]

As of September 30, 2019, maturities of operating lease liabilities were as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remaining three months of 2019	$	6	$	—	$	1
2020	22		1		5
2021	15		—		5
2022	9		—		4
2023	7		—		3
2024	3		—		2
2025 and beyond	12		—		9
Total lease payments	74		1		29
Less: Interest	7		—		4
Present value of lease liabilities	$	67	$	1	$	25

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

The following table sets forth information concerning the Registrants’ obligations under non-cancelable long-term operating leases as of December 31, 2018:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2019	$	6	$	1	$	5
2020	6		—		5
2021	5		—		4
2022	4		—		4
2023	3		—		3
2024 and beyond	12		—		11
Total (1)	$	36	$	1	$	32


(1)	The Merger was completed on February 1, 2019. As such, these amounts are exclusive of Vectren’s leases.

Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]

As of September 30, 2019, maturities of undiscounted operating lease payments to be received are as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Remaining three months of 2019	$	1	$	—	$	—
2020	2		1		—
2021	2		—		—
2022	2		—		—
2023	2		—		—
2024	2		—		—
2025 and beyond	10		—		—
Total lease payments to be received	$	21	$	1	$	—

Other Information Related To Leases [Table Text Block]

Other information related to leases is as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019						2019
	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	$	6	$	—	$	2	$	18	$	1	$	4

Equity (Tables)

9 Months Ended

Sep. 30, 2019

Equity [Abstract]

Dividends Declared [Table Text Block]

CenterPoint Energy paid dividends on its Common Stock during the nine months ended September 30, 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 21, 2019	March 14, 2019	$	0.2875	$	144
April 25, 2019	May 16, 2019	June 13, 2019	0.2875		144
July 31, 2019	August 15, 2019	September 12, 2019	0.2875		145
Total 2019			$	0.8625	$	433

December 13, 2017	February 15, 2018	March 8, 2018	$	0.2775	$	120
April 26, 2018	May 17, 2018	June 14, 2018	0.2775		120
July 26, 2018	August 16, 2018	September 13, 2018	0.2775		120
Total 2018			$	0.8325	$	360

CenterPoint Energy declared no dividends on its Series A Preferred Stock or Series B Preferred Stock during the three or nine months ended September 30, 2018.

CenterPoint Energy paid dividends on its Series A Preferred Stock during the nine months ended September 30, 2019 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	32.1563	$	26
July 31, 2019	August 15, 2019	September 3, 2019	30.6250		24
Total 2019			$	62.7813	$	50

CenterPoint Energy paid dividends on its Series B Preferred Stock during the nine months ended September 30, 2019 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	17.5000	$	17
April 25, 2019	May 15, 2019	June 3, 2019	17.5000		17
July 31, 2019	August 15, 2019	September 3, 2019	17.5000		17
Total 2019			$	52.5000	$	51

Dividend Requirement on Preferred Stock (CenterPoint Energy)



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Series A Preferred Stock	$	12	$	5	$	37	$	5
Series B Preferred Stock	17		—		51		—
Total preferred stock dividend requirement	$	29	$	5	$	88	$	5

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

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



	Three Months Ended September 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric		CERC
	(in millions)
Beginning Balance	$	(105	)	$	(15	)	$	5	$	(62	)	$	4	$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(2		)	—			—		4			3		—
Other comprehensive loss from unconsolidated affiliates	(2		)	—			—		—			—		—
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	2			—			—		2			—		—
Tax expense	—			—			—		(2		)	—		—
Net current period other comprehensive income	(2		)	—			—		4			3		—
Ending Balance	$	(107	)	$	(15	)	$	5	$	(58	)	$	7	$	6



	Nine Months Ended September 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning Balance	$	(108	)	$	(14	)	$	5	$	(68	)	$	—		$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(3		)	(1		)	—		8			8			—
Other comprehensive loss from unconsolidated affiliates	(2		)	—			—		—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—		1			—			—
Actuarial losses (2)	6						—		5			—			—
Reclassification of deferred loss from cash flow hedges realized in net income	1			—			—		—			—			—
Tax expense	(2		)	—			—		(4		)	(1		)	—
Net current period other comprehensive income (loss)	1			(1		)	—		10			7			—
Ending Balance	$	(107	)	$	(15	)	$	5	$	(58	)	$	7		$	6

(1)

(2)

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

Subsequent Events (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2019

Subsequent Events [Abstract]

Schedule of Subsequent Events [Table Text Block]

CenterPoint Energy Dividend Declarations



Equity Instrument	Declaration Date	Record Date	Payment Date	Per Share
Common Stock	October 17, 2019	November 21, 2019	December 12, 2019	$	0.2875
Series B Preferred Stock	October 17, 2019	November 15, 2019	December 2, 2019	17.5000

Enable Distributions Declarations (CenterPoint Energy)

Equity Instrument

Declaration Date

Record Date

Payment Date

Per Unit Distribution

Expected Cash Distribution

(in millions)

Enable common units

November 5, 2019

November 19, 2019

November 26, 2019

0.3305

Enable Series A Preferred Units

November 5, 2019

November 14, 2019

0.6250

Background and Basis of Presentation (Details)
$ in Millions

9 Months Ended

Sep. 30, 2019

USD ($)

state

Ownership percentage of equity method investment

53.70%

^[1]

Enable Midstream Partners [Member] | Series A Preferred Units [Member]

Preferred units held | shares

14,520,000

^[2]

Number of states in which entity operates

Number of states in which entity operates

Enable GP, LLC [Member] | CenterPoint Energy [Member]

Management rights ownership percentage

50.00%

^[3],[4]

Incentive distribution right

40.00%

^[4],[5]

Amount of cash to be paid to acquire Vectren | $

$ 5,982

[1]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[2]	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of September 30, 2019 and $363 million as of December 31, 2018. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods.
[3]	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.
[4]	Held indirectly through CNP Midstream.
[5]	Enable is expected to pay a minimum quarterly distribution of $0.2875 per common unit on its outstanding common units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to Enable GP and its affiliates, within 60 days after the end of each quarter. If cash distributions to Enable’s unitholders exceed $0.330625 per common unit in any quarter, Enable GP will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances Enable GP will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election. To date, no incentive distributions have been made.

Mergers and Acquisitions (CenterPoint Energy) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

12 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Dec. 31, 2018

Preliminary purchase price allocation [Abstract]

$ 0.2875

$ 0.2775

$ 0.5750

$ 0.5550

Identifiable intangible assets preliminary purchase price allocation [Abstract]

$ 5,179

$ 867

Business Combinations, Additional Disclosures [Abstract]

$ 0

Non-utility cost of revenues [Member]

2,742

$ 2,212

9,071

7,553

Net income (Loss)

270

158

634

248

Identifiable intangible assets preliminary purchase price allocation [Abstract]

Depreciation and amortization expense [Member]

^[1]

Identifiable intangible assets preliminary purchase price allocation [Abstract]

^[2]

$ 7

Cash to be paid per share of Vectren common stock prior to closing of the Merger

$ 5,982

$ 72.00

Preliminary purchase price allocation [Abstract]

Property, plant and equipment, net

$ 16

Other current assets

598

5,146

Identifiable intangibles

322

338

Other assets

151

Total assets acquired

6,571

Current liabilities

690

944

Other liabilities

860

Total liabilities assumed

2,401

4,895

Net assets acquired

1,676

4,306

Identifiable intangible assets preliminary purchase price allocation [Abstract]

5,982

Business Combinations, Additional Disclosures [Abstract]

322

Vectren [Member] | Depreciation and amortization expense [Member]

756

1,917

Net income (Loss)

Pro Forma Information [Abstract]

Operating revenues

2,742

2,877

9,317

9,521

Net income

279

$ 212

^[3]

649

^[4]

282

^[5]

Identifiable intangible assets preliminary purchase price allocation [Abstract]

Vectren [Member] | Operation and maintenance expense [Member]

^[2]

Severance expense related to the Merger

Business Combinations, Additional Disclosures [Abstract]

Business Combination, Integration Related Costs

$ 67

Vectren [Member] | Operation and maintenance agreements [Member]

Identifiable intangible assets preliminary purchase price allocation [Abstract]

24 years

Vectren [Member] | Customer Relationships [Member]

$ 12

Identifiable intangible assets preliminary purchase price allocation [Abstract]

18 years

Vectren [Member] | Construction Backlog [Member]

$ 220

Identifiable intangible assets preliminary purchase price allocation [Abstract]

1 year

Vectren [Member] | Trade Names [Member]

$ 28

Identifiable intangible assets preliminary purchase price allocation [Abstract]

10 years

Vectren [Member] | Operation and maintenance agreements and construction backlog [Member] | Non-utility cost of revenues [Member]

$ 62

Identifiable intangible assets preliminary purchase price allocation [Abstract]

Vectren [Member] | Customer relationships and trade names [Member] | Depreciation and amortization expense [Member]

Identifiable intangible assets preliminary purchase price allocation [Abstract]

Vectren [Member] | Stub period [Member]

^[2]

$ 13

Vectren acquisition [Member]

$ 0.41145

Cash payments towards outstanding share-based awards

$ 78

Share-based award liability recorded

Incremental share-based awards expense recorded

Utility pipeline construction company [Member]

Preliminary purchase price allocation [Abstract]

Identifiable intangibles

$ 6

Vectren [Member] | Pro Forma Adjustment [Member] | Vectren acquisition [Member]

Pro Forma Information [Abstract]

Merger-related expenses

$ 37

$ 18

CenterPoint Energy [Member] | Pro Forma Adjustment [Member] | Vectren acquisition [Member]

Pro Forma Information [Abstract]

Merger-related expenses

$ 1

[1]	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.
[2]	Includes $5 million and $13 million for the three and nine months ended September 30, 2019, respectively, of amortization expense related to intangibles acquired in the Merger. The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.
[3]	Pro forma net income was adjusted to exclude $18 million of Vectren Merger-related transaction costs incurred in 2018 and reflected in the historical income statements.
[4]	Pro forma net income was adjusted to exclude $37 million of Vectren Merger-related transaction costs incurred in 2019.
[5]	Pro forma net income was adjusted to include $38 million and $1 million, respectively, of Vectren and CenterPoint Energy Merger-related transaction costs incurred from October 1, 2018 to September 30, 2019.

Revenue Recognition Disaggregation of Revenue (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

$ 2,093

$ 1,385

$ 6,688

$ 4,960

664

838

2,508

2,723

^[1]

(2)

(47)

Houston Electric T&D [Member]

2,742

2,212

9,071

7,553

Indiana Electric Integrated [Member]

^[2]

859

897

2,313

2,502

165

388

515

402

2,554

2,032

Infrastructure Services [Member]

734

910

2,754

3,008

Corporate and Other [Member]

376

847

Intersegment Eliminations [Member]

215

Intersegment Eliminations [Member] | Houston Electric T&D [Member]

(21)

(18)

(123)

(83)

Intersegment Eliminations [Member] | Indiana Electric Integrated [Member]

Intersegment Eliminations [Member] | Natural Gas Distribution [Member]

Intersegment Eliminations [Member] | Energy Services [Member]

(9)

(8)

(29)

(26)

Intersegment Eliminations [Member] | Infrastructure Services [Member]

(11)

(10)

(92)

(57)

Intersegment Eliminations [Member] | Corporate and Other [Member]

(1)

(2)

Reportable Subsegments [Member] | Houston Electric T&D [Member]

^[3]

861

904

2,319

2,525

^[3]

(4)

^[1],[3]

(2)

(7)

(9)

(19)

Reportable Subsegments [Member] | Indiana Electric Integrated [Member]

^[3]

859

897

2,313

2,502

^[3]

165

388

^[4]

^[3]

^[4]

^[1],[3]

^[4]

Reportable Subsegments [Member] | Natural Gas Distribution [Member]

^[3]

165

388

^[4]

^[3]

518

398

2,581

^[4]

2,093

^[3]

^[4],[5]

^[1],[3]

^[4]

(35)

Reportable Subsegments [Member] | Energy Services [Member]

^[3]

515

402

2,554

^[4]

2,032

^[6]

341

338

^[6]

664

838

2,505

2,727

^[1],[6]

Reportable Subsegments [Member] | Infrastructure Services [Member]

^[6]

734

910

2,754

3,008

^[6]

377

849

^[4]

^[6]

^[4]

^[1],[6]

^[4]

Reportable Subsegments [Member] | Corporate and Other [Member]

^[6]

376

847

^[4]

^[6]

210

^[4]

^[6]

^[4]

^[1],[6]

^[4]

Reportable Subsegments [Member] | Intersegment Eliminations [Member]

^[6]

215

^[4]

^[3]

(9)

(8)

(29)

^[4]

(26)

^[6]

(11)

(10)

(92)

(57)

Reportable Subsegments [Member] | Intersegment Eliminations [Member] | Infrastructure Services [Member]

(21)

(18)

(123)

(83)

^[6]

(1)

(2)

^[4]

Houston Electric [Member] | Reportable Subsegments [Member] | Houston Electric T&D [Member]

859

897

2,310

2,506

861

904

2,319

2,525

^[7]

(2)

(7)

(9)

(19)

859

897

2,310

2,506

477

480

2,446

2,431

664

838

2,505

2,727

^[8]

(35)

CERC Corp [Member] | Natural Gas Distribution [Member]

1,126

1,312

4,836

5,040

CERC Corp [Member] | Energy Services [Member]

389

402

2,077

2,032

CERC Corp [Member] | Corporate and Other [Member]

734

910

2,755

3,008

CERC Corp [Member] | Intersegment Eliminations [Member]

CERC Corp [Member] | Intersegment Eliminations [Member] | Natural Gas Distribution [Member]

(20)

(18)

(120)

(83)

CERC Corp [Member] | Intersegment Eliminations [Member] | Energy Services [Member]

(9)

(8)

(29)

(26)

CERC Corp [Member] | Intersegment Eliminations [Member] | Corporate and Other [Member]

(11)

(10)

(91)

(57)

CERC Corp [Member] | Reportable Subsegments [Member] | Natural Gas Distribution [Member]

^[5]

393

398

2,101

2,093

^[5]

^[5],[8]

(35)

CERC Corp [Member] | Reportable Subsegments [Member] | Energy Services [Member]

^[5]

389

402

2,077

2,032

^[9]

341

338

^[9]

664

838

2,505

2,727

^[8],[9]

CERC Corp [Member] | Reportable Subsegments [Member] | Corporate and Other [Member]

^[9]

734

910

2,755

3,008

^[9]

^[9]

^[8],[9]

CERC Corp [Member] | Reportable Subsegments [Member] | Intersegment Eliminations [Member]

^[9]

^[5]

(9)

(8)

(29)

(26)

^[9]

(11)

(10)

(91)

(57)

Change in Accounts Receivable [Roll Forward]

$ (20)

$ (18)

$ (120)

$ (83)

[1]

[2]

Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192

[3]

Reflected in Utility revenues in the Condensed Statements of Consolidated Income

[4]

Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to September 30, 2019.

[5]

Reflected in Utility revenues in the Condensed Statements of Consolidated Income.

[6]

Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

[7]

[8]

[9]

Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

Revenue Recognition Summary of Contract Assets and Liabilities (Details)
$ in Millions

9 Months Ended

Sep. 30, 2019

USD ($)

$ 763

^[1]

Increase (Decrease) in Accounts Receivable

779

Change in Other Accrued Unbilled Revenues [Roll Forward]

575

^[1]

Increase (Decrease) in Other Accrued Unbilled Revenues

403

(172)

Change in Contract Asset [Roll Forward]

^[1]

Increase (Decrease) in Contract with Customer, Asset

Change in Contract Liability [Roll Forward]

^[1]

Increase (Decrease) in Contract with Customer, Liability

(5)

Contract with Customer, Liability, Revenue Recognized

Change in Accounts Receivable [Roll Forward]

234

Increase (Decrease) in Accounts Receivable

325

Change in Other Accrued Unbilled Revenues [Roll Forward]

110

Increase (Decrease) in Other Accrued Unbilled Revenues

136

Change in Contract Liability [Roll Forward]

Increase (Decrease) in Contract with Customer, Liability

Contract with Customer, Liability, Revenue Recognized

Change in Accounts Receivable [Roll Forward]

282

Increase (Decrease) in Accounts Receivable

137

(145)

Change in Other Accrued Unbilled Revenues [Roll Forward]

263

Increase (Decrease) in Other Accrued Unbilled Revenues

$ (181)

[1]	Opening balances related to Vectren are as of February 1, 2019.

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Sep. 30, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 365
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	365
Operations and Maintenance and Other [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	365
Operations and Maintenance and Other [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	0
Operations and Maintenance and Other [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 365

Employee Benefit Plans (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Jun. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Pension Benefits [Member]

$ 24

$ 16

$ 70

$ 46

Other Postretirement Benefits Plan [Member]

Operation and maintenance expense [Member] | Pension Benefits [Member]

Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]

^[1]

Other, net [Member] | Pension Benefits [Member]

^[2]

^[3]

^[3]

(27)

(79)

(80)

Amortization of net loss (2)

^[3]

^[3]

Settlement cost (3) (2)

^[3],[4]

$ 1

^[3],[4]

Curtailment gain (4) (2)

^[3],[5]

(1)

Other, net [Member] | Other Postretirement Benefits Plan [Member]

^[6]

^[6]

(3)

(1)

(6)

(4)

Houston Electric [Member] | Other Postretirement Benefits Plan [Member]

^[6]

(1)

(3)

(1)

(2)

(1)

Houston Electric [Member] | Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]

Houston Electric [Member] | Other, net [Member] | Other Postretirement Benefits Plan [Member]

^[2]

^[6]

^[6]

(1)

(3)

CERC Corp [Member] | Other Postretirement Benefits Plan [Member]

^[6]

(1)

(4)

CERC Corp [Member] | Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]

CERC Corp [Member] | Other, net [Member] | Other Postretirement Benefits Plan [Member]

^[2]

^[6]

^[6]

(1)

Securitized regulatory assets

^[6]

$ 0

$ 1

[1]	Amounts presented in the table 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 Operation and maintenance expense in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.
[3]	Amounts presented in the table above are included in Other income (expense), net in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of regulatory deferrals.
[4]	A one-time, non-cash settlement cost is 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. CenterPoint Energy recognized a non-cash settlement cost of $1 million in June and September 2019, respectively, due to lump sum settlement payments.
[5]	A curtailment gain or loss is required when the expected future services of a significant number of employees are reduced or eliminated for the accrual of benefits. In February 2019, CenterPoint Energy recognized a pension curtailment gain of $1 million related to Vectren employees whose employment was terminated after the Merger closed.
[6]	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.

Regulatory Matters (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 16, 2019

Apr. 05, 2019

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

$ 821.0

$ 1,059.0

Unrecognized equity return (2)

^[1]

(175.0)

(213.0)

Unamortized loss on reacquired debt (3)

^[2]

63.0

68.0

2,194.0

1,967.0

2,212.0

2,044.0

Total regulatory liabilities

3,481.0

2,525.0

3,512.0

2,563.0

Total regulatory assets and liabilities, net

(1,300.0)

(519.0)

Amount of allowed equity return on the true-up balance that was recognized in the period

14.0

$ 17.0

38.0

$ 62.0

Securitized regulatory assets

821.0

1,059.0

Unrecognized equity return (2)

^[1]

(175.0)

(213.0)

Unamortized loss on reacquired debt (3)

^[2]

63.0

68.0

951.0

1,124.0

951.0

1,124.0

Total regulatory liabilities

1,295.0

1,298.0

1,295.0

1,315.0

Total regulatory assets and liabilities, net

(344.0)

(191.0)

Amount of allowed equity return on the true-up balance that was recognized in the period

14.0

$ 17.0

38.0

$ 62.0

Securitized regulatory assets

0.0

Unrecognized equity return (2)

0.0

Unamortized loss on reacquired debt (3)

0.0

189.0

181.0

207.0

258.0

Total regulatory liabilities

1,221.0

1,227.0

1,249.0

1,248.0

Total regulatory assets and liabilities, net

(1,042.0)

(990.0)

Hurricane Harvey [Member]

Hurricane Harvey [Member] | Houston Electric [Member]

^[2]

68.0

Hurricane Harvey [Member] | CERC Corp [Member]

^[2]

64.0

Prepaid expenses and other current assets [Member]

^[2]

4.0

Current regulatory assets (1)

^[3]

18.0

77.0

Prepaid expenses and other current assets [Member] | Houston Electric [Member]

Current regulatory assets (1)

^[3]

0.0

Prepaid expenses and other current assets [Member] | CERC Corp [Member]

Current regulatory assets (1)

^[3]

18.0

77.0

Other current liabilities [Member]

Current regulatory liabilities (6)

^[4]

31.0

38.0

Other current liabilities [Member] | Houston Electric [Member]

Current regulatory liabilities (6)

^[4]

0.0

17.0

Other current liabilities [Member] | CERC Corp [Member]

Current regulatory liabilities (6)

^[4]

28.0

21.0

Asset Retirement Obligation Costs [Member]

Asset Retirement Obligation Costs [Member] | Houston Electric [Member]

^[2]

139.0

109.0

Asset Retirement Obligation Costs [Member] | CERC Corp [Member]

^[2]

25.0

24.0

Pension and Other Postretirement Plans Costs [Member]

^[2]

92.0

85.0

Pension and Other Postretirement Plans Costs [Member] | Houston Electric [Member]

^[2]

683.0

725.0

Pension and Other Postretirement Plans Costs [Member] | CERC Corp [Member]

^[2]

35.0

33.0

Amounts related to TCJA [Member]

^[2]

27.0

30.0

^[2],[5]

30.0

33.0

^[2],[5]

23.0

Other Regulatory Assets (Liabilities) [Member]

^[2],[5]

7.0

10.0

Other regulatory assets-not earning a return (5)

411.0

37.0

^[6]

154.0

81.0

Other Regulatory Assets (Liabilities) [Member] | Houston Electric [Member]

Other regulatory assets-not earning a return (5)

30.0

11.0

^[6]

65.0

55.0

Other Regulatory Assets (Liabilities) [Member] | CERC Corp [Member]

Other regulatory assets-not earning a return (5)

13.0

26.0

^[6]

46.0

26.0

Amounts related to TCJA [Member]

^[5]

1,606.0

1,323.0

^[5]

830.0

847.0

^[5]

449.0

476.0

Removal Costs [Member]

Removal Costs [Member] | Houston Electric [Member]

1,430.0

886.0

Removal Costs [Member] | CERC Corp [Member]

259.0

269.0

Other Regulatory Assets (Liabilities) [Member]

634.0

617.0

Other Regulatory Assets (Liabilities) [Member] | Houston Electric [Member]

445.0

316.0

Other Regulatory Assets (Liabilities) [Member] | CERC Corp [Member]

206.0

182.0

CenterPoint Energy Houston Electric 2019 Rate Case [Member]

$ 138.0

$ 134.0

Requested revenue increase

$ 194.0

Rate Base

$ 6,400.0

Requested Debt Capital Structure, Percentage

50.00%

Requested Equity Capital Structure, Percentage

50.00%

Requested Return on Equity, Percentage

10.40%

Public Utility Commission of Texas [Member] | Administrative Law Judge Proposal for Decision [Member]

Requested revenue increase

$ 2.6

Rate Base disallowance of assets

120.0

Excess deferred income taxes on securitized assets

$ 158.0

[1]



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Allowed equity return recognized	$	14	$	14	$	17	$	17	$	38	$	38	$	62	$	62

[2]

Substantially all of these regulatory assets are not earning a return.

[3]

Current regulatory assets are included in Prepaid expenses and other current assets in the Registrants’ respective Condensed Consolidated Balance Sheets.

[4]

Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Condensed Consolidated Balance Sheets.

[5]

The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities.

[6]

Regulatory assets acquired in the Merger and not earning a return were recorded at fair value as of the Merger Date. Such fair value adjustments are recognized over time until the regulatory asset is recovered.

Derivative Instruments Derivatives and Hedging (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

Weather hedges term

10 years

$ 277

$ 220

Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member]

1,057

833

2018 to 2019 [Member] | Natural Gas Distribution [Member]

^[1]

$ 0

$ (4)

2018 to 2019 [Member] | Houston Electric T&D [Member]

2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Houston Electric T&D [Member]

2017to2018 [Member] | Natural Gas Distribution [Member]

2017to2018 [Member] | Houston Electric T&D [Member]

2017to2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

2017to2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Houston Electric T&D [Member]

(4)

277

220

CERC Corp [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member]

205

208

CERC Corp [Member] | 2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

^[1]

CERC Corp [Member] | 2017to2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Contract [Member]

$ 0

Not Designated as Hedging Instrument, Economic Hedge [Member] | Houston Electric [Member] | Interest Rate Contract [Member]

^[2]

Cash Flow Hedging [Member] | Interest Rate Contract [Member]

Cash Flow Hedging [Member] | Houston Electric [Member] | Interest Rate Contract [Member]

^[2]

450

$ 0

$ 450

[1]	Weather hedge gains (losses) are recorded in Revenues in the Condensed Statements of Consolidated Income.
[2]	Relates to interest rate derivative instruments at SIGECO.

Derivative Instruments Summary of Derivative Activity (Details)
$ in Millions

3 Months Ended

9 Months Ended

12 Months Ended

Sep. 30, 2019

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2019

USD ($)

Bcf

Sep. 30, 2018

USD ($)

Dec. 31, 2018

USD ($)

Bcf

$ 277

$ 220

1,057

833

Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item

(7)

Total amounts presented in the statements of income in which the effects of hedges are recorded

^[1]

852

$ 864

3,013

$ 2,927

Gain (loss) on derivative instruments not designated as hedging instruments

(42)

(57)

(246)

Aggregate fair value of derivatives containing material adverse change provisions in a net liability position

Fair value of collateral already posted

Additional collateral required to be posted if credit risk contingent features triggered

Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Liabilities [Member]

Energy Related Derivative [Member]

$ 15

$ 0

Derivative gross volume notional amount (in Bcf) | Bcf

2,252

1,674

Net amount presented in the consolidated balance sheets

^[2]

102

$ 102

$ 31

Gross Amounts Offset in the Consolidated Balance Sheets

^[3]

Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item

^[2]

120

100

(7)

^[3]

199

166

(79)

(66)

^[2]

^[3]

(14)

(16)

^[3]

(157)

(183)

107

^[2]

(50)

(102)

^[3]

(68)

(25)

^[2]

(32)

(5)

^[4],[5],[6]

123

103

^[4],[5],[6]

^[4],[5],[6]

^[4],[5],[6]

^[4],[5],[6]

^[4],[5],[6]

154

173

^[4],[5],[6]

^[4],[5],[6]

$ 68

$ 25

Derivative gross volume notional amount (in Bcf) | Bcf

374

140

IDS Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]

$ 0

817

601

277

220

205

208

Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item

(7)

Total amounts presented in the statements of income in which the effects of hedges are recorded

^[1]

687

864

2,627

2,927

Gain (loss) on derivative instruments not designated as hedging instruments

159

Aggregate fair value of derivatives containing material adverse change provisions in a net liability position

Fair value of collateral already posted

Additional collateral required to be posted if credit risk contingent features triggered

$ 1

$ 0

CERC Corp [Member] | Energy Related Derivative [Member]

Derivative gross volume notional amount (in Bcf) | Bcf

2,252

1,674

Net amount presented in the consolidated balance sheets

^[2]

122

$ 122

$ 31

Gross Amounts Offset in the Consolidated Balance Sheets

^[3]

CERC Corp [Member] | Energy Related Derivative [Member] | Current Assets [Member]

Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item

^[2]

120

100

(7)

^[3]

199

166

CERC Corp [Member] | Energy Related Derivative [Member] | Other Assets [Member]

(79)

(66)

^[2]

^[3]

CERC Corp [Member] | Energy Related Derivative [Member] | Current Liabilities [Member]

(14)

(16)

^[3]

(151)

(183)

107

CERC Corp [Member] | Energy Related Derivative [Member] | Other Liabilities [Member]

^[2]

(44)

(102)

^[3]

(54)

(25)

CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]

^[2]

(18)

(5)

^[7],[8],[9]

123

103

CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Assets [Member]

^[7],[8],[9]

^[7],[8],[9]

CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]

^[7],[8],[9]

^[7],[8],[9]

CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Liabilities [Member]

^[7],[8],[9]

148

173

^[7],[8],[9]

CERC Corp [Member] | Energy Related Derivative [Member] | Long [Member]

^[7],[8],[9]

$ 54

$ 25

Derivative gross volume notional amount (in Bcf) | Bcf

374

140

Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Designated as Fair Value Hedge [Member] | Current Liabilities [Member]

$ 0

Cash Flow Hedging [Member] | Houston Electric [Member] | Interest Rate Contract [Member] | Designated as Fair Value Hedge [Member] | Current Liabilities [Member]

Fair Value Hedging [Member] | Energy Related Derivative [Member] | Current Assets [Member]

Fair Value Hedging [Member] | Energy Related Derivative [Member] | Designated as Fair Value Hedge [Member] | Current Liabilities [Member]

^[4],[5],[6]

Fair Value Hedging [Member] | CERC Corp [Member] | Energy Related Derivative [Member] | Current Assets [Member]

^[4],[5],[6]

Fair Value Hedging [Member] | CERC Corp [Member] | Energy Related Derivative [Member] | Designated as Fair Value Hedge [Member] | Current Liabilities [Member]

^[7],[8],[9]

Gains (Losses) in Revenue [Member] | Energy Related Derivative [Member]

^[7],[8],[9]

$ 7

Gain (loss) on derivative instruments not designated as hedging instruments

159

Gains (Losses) in Revenue [Member] | CERC Corp [Member] | Energy Related Derivative [Member]

Gain (loss) on derivative instruments not designated as hedging instruments

159

Non-utility Natural Gas Expense [Member] | Fair Value Hedging [Member] | Energy Related Derivative [Member]

Change in unrealized gain (loss) on fair value hedging instruments

^[1]

(8)

(13)

Amounts excluded from effectiveness testing recognized in earnings immediately

^[1]

(59)

(138)

(73)

Non-utility Natural Gas Expense [Member] | Fair Value Hedging [Member] | Energy Related Derivative [Member] | Designated as Fair Value Hedge [Member]

Change in unrealized gain (loss) on fair value hedging instruments

^[1]

(2)

(1)

Non-utility Natural Gas Expense [Member] | Fair Value Hedging [Member] | CERC Corp [Member] | Energy Related Derivative [Member]

Change in unrealized gain (loss) on fair value hedging instruments

^[1]

(8)

(13)

Amounts excluded from effectiveness testing recognized in earnings immediately

^[1]

(59)

(138)

(73)

Non-utility Natural Gas Expense [Member] | Fair Value Hedging [Member] | CERC Corp [Member] | Energy Related Derivative [Member] | Designated as Fair Value Hedge [Member]

Change in unrealized gain (loss) on fair value hedging instruments

^[1]

(2)

(1)

Gains (Losses) in Other Income (Expense) [Member] | IDS Derivative [Member]

Gain (loss) on derivative instruments not designated as hedging instruments

$ (62)

$ (44)

$ (216)

$ (316)

[1]	Income statement impact associated with cash flow hedge activity is related to gains and losses reclassified from Accumulated other comprehensive income into income. Amounts are immaterial for each Registrant in the three and nine months ended September 30, 2019 and 2018, respectively.
[2]	The derivative assets and liabilities on the Registrant’s respective Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.
[3]	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.
[4]	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.
[5]	Natural gas contracts are presented on a net basis in CenterPoint Energy’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CenterPoint Energy’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.
[6]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.
[7]	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.
[8]	Natural gas contracts are presented on a net basis in CERC’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CERC’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.
[9]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,252 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

Fair Value Measurements (Details)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2019

USD ($)

Sep. 30, 2018

USD ($)

Dec. 31, 2018

USD ($)

Assets

$ 42

$ 57

Total derivative assets, netting adjustment

982

747

^[1]

(93)

(82)

Total derivative liabilities, netting adjustment

921

732

^[1]

(143)

(101)

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

Beginning balance

$ (628)

$ (622)

Total gains

Total settlements

(1)

(18)

(36)

Transfers into Level 3

(1)

(2)

Transfers out of Level 3

(2)

650

(6)

678

Ending balance (1)

^[2]

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:

Carrying Amount [Member]

^[3]

14,861

9,140

Fair Value [Member]

Energy Related Derivative [Member]

^[3]

15,994

9,308

Derivative fair value offsets, net

Fair Value, Inputs, Level 1 [Member]

Assets

798

609

Fair Value, Inputs, Level 2 [Member]

Assets

234

173

Fair Value, Inputs, Level 3 [Member]

1,035

792

Assets

Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member] | Minimum [Member]

$ 22

Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]

Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member] | Maximum [Member]

1.38

Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]

Fair Value, Measurements, Recurring [Member]

6.09

Assets

748

$ 748

542

Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member]

^[4]

Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member]

Assets

Derivative asset, netting adjustment

^[1],[5],[6]

(93)

(82)

^[5],[6]

184

138

Derivative liabilities, netting adjustment

^[1],[5],[6]

(143)

(101)

Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member]

^[5],[6]

107

Derivative liabilities, netting adjustment

^[1]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

817

601

Assets

748

542

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Interest Rate Contract [Member]

^[4]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Energy Related Derivative [Member]

Assets

^[5],[6]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | IDS Derivative [Member]

^[5],[6]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]

^[4]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Energy Related Derivative [Member]

Assets

^[5],[6]

234

173

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | IDS Derivative [Member]

^[5],[6]

203

191

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

817

601

Assets

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Interest Rate Contract [Member]

^[4]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Energy Related Derivative [Member]

Assets

^[5],[6]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | IDS Derivative [Member]

^[5],[6]

Assets

Total derivative assets, netting adjustment

Total derivative liabilities, netting adjustment

Houston Electric [Member] | Carrying Amount [Member]

Houston Electric [Member] | Fair Value [Member]

^[3]

5,018

4,717

Houston Electric [Member] | Fair Value, Inputs, Level 1 [Member]

^[3]

5,595

4,770

Assets

Houston Electric [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

Houston Electric [Member] | Fair Value, Inputs, Level 3 [Member]

Assets

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member]

Assets

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member]

^[4]

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

Assets

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Interest Rate Contract [Member]

^[4]

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]

^[4]

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

Assets

Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Interest Rate Contract [Member]

^[4]

Assets

Total derivative assets, netting adjustment

197

152

^[1]

(93)

(82)

Total derivative liabilities, netting adjustment

107

^[1]

(143)

(101)

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

Beginning balance

Total gains

Total settlements

(1)

(18)

(36)

Transfers into Level 3

(1)

(2)

Transfers out of Level 3

(2)

(6)

Ending balance (1)

^[2]

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:

$ 11

$ 9

CERC Corp [Member] | Carrying Amount [Member]

CERC Corp [Member] | Fair Value [Member]

2,477

2,371

CERC Corp [Member] | Energy Related Derivative [Member]

2,783

2,488

Derivative fair value offsets, net

CERC Corp [Member] | Fair Value, Inputs, Level 1 [Member]

Assets

CERC Corp [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

234

173

CERC Corp [Member] | Fair Value, Inputs, Level 3 [Member]

183

191

Assets

CERC Corp [Member] | Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member] | Minimum [Member]

$ 22

Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]

CERC Corp [Member] | Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member] | Maximum [Member]

1.38

Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member]

6.09

Assets

$ 2

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member]

^[4]

Assets

Derivative asset, netting adjustment

^[1],[5],[6]

(93)

(82)

^[5],[6]

184

138

Derivative liabilities, netting adjustment

^[1],[5],[6]

(143)

(101)

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

^[5],[6]

107

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Energy Related Derivative [Member]

^[4]

Assets

^[5],[6]

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

^[5],[6]

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Energy Related Derivative [Member]

^[4]

Assets

^[5],[6]

234

173

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

^[5],[6]

183

191

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Energy Related Derivative [Member]

^[4]

Assets

^[5],[6]

Natural gas inventory [Member] | Fair Value, Measurements, Recurring [Member]

^[5],[6]

Assets

Natural gas inventory [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

Assets

Natural gas inventory [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

Natural gas inventory [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

Assets

Natural gas inventory [Member] | CERC Corp [Member] | Fair Value, Measurements, Recurring [Member]

Assets

Natural gas inventory [Member] | CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

Assets

Natural gas inventory [Member] | CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

Assets

Natural gas inventory [Member] | CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

Assets

$ 0

[1]

Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy and CERC to settle positive and negative positions and also include cash collateral posted with the same counterparties as follows:



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	50	$	50	$	19	$	19

[2]

CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during the three or nine months ended September 30, 2019 or 2018.

[3]

Includes Securitization Bonds debt.

[4]

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

[5]

[6]

Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Oct. 30, 2019

Dec. 31, 2018

Preferred units – unconsolidated affiliate

$ 363

Percentage of sales that trigger right of first refusal

5.00%

Total distributions received from Enable

$ 83

$ 253

$ 250

Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]

Equity in earnings of unconsolidated affiliate, net

213

208

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

Investment in unconsolidated affiliates

2,469

2,482

Total distributions received from Enable

223

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Income tax expense

Income from discontinued operations (net of tax of $-0-, $13, $-0- and $44, respectively)

$ 0

140

Enable's common unit price

$ 12.03

OGE [Member]

Percentage of sales that trigger right of first refusal

5.00%

Proliance Holdings LLC [Member]

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

Investment in unconsolidated affiliates

$ 2

^[1]

$ 2

^[1]

Ownership percentage of equity method investment

^[2]

53.70%

Carrying value per unit of investment in Enable

$ 10.55

Amount above carrying value

$ 347

Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]

Operating revenues

699

928

2,229

2,481

Cost of sales, excluding depreciation and amortization

263

516

958

1,335

Net income attributable to Enable common units

108

100

323

292

Operating income

175

171

507

436

123

129

351

320

CenterPoint Energy’s interest

189

173

Basis difference amortization (1)

^[3]

Loss on dilution, net of proportional basis difference recognition

(11)

Equity in earnings of unconsolidated affiliate, net

213

208

Equity Method Investment, Summarized Financial Information, Assets and Liabilities [Abstract]

Current assets

417

449

Non-current assets

12,018

11,995

Current liabilities

819

1,615

Non-current liabilities

4,076

3,211

Non-controlling interest

Preferred equity

362

Accumulated other comprehensive loss

(4)

Enable partners’ equity

7,145

7,218

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s ownership interest in Enable partners’ equity

3,838

3,896

CenterPoint Energy’s basis difference

(1,371)

(1,414)

Investment in unconsolidated affiliates

2,467

2,482

Enable Midstream Partners [Member] | Common Units [Member]

Distributions received from Enable equity method investment

^[4]

$ 77

$ 74

$ 226

$ 223

Distribution per share of common units

$ 0.3305

$ 0.3180

$ 0.9665

$ 0.9540

Enable Midstream Partners [Member] | Series A Preferred Units [Member]

Distributions received from Enable cost method investment

$ 9

$ 27

Distribution per share of Series A preferred units

$ 0.6250

$ 1.8750

Enable Midstream Partners [Member] | CERC Corp [Member] | Common Units [Member]

Distributions received from Enable equity method investment

^[4]

$ 74

$ 223

Distribution per share of common units

$ 0.3180

$ 0.9540

Common Units [Member] | Enable Midstream Partners [Member]

Series A Preferred Units [Member] | Enable Midstream Partners [Member]

^[5]

233,856,623

Transitional Service [Member] | Enable Midstream Partners [Member]

Preferred Units Held

^[6]

14,520,000

Reimbursement of support services (2)

^[7]

$ 0

$ 1

$ 3

$ 4

Accounts receivable for amounts billed for services provided to Enable

Transitional Service [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]

Reimbursement of support services (2)

^[7]

Accounts receivable for amounts billed for services provided to Enable

Natural Gas Expenses [Member] | Enable Midstream Partners [Member]

Natural gas expenses, including transportation and storage costs (1)

^[8]

Accounts payable for natural gas purchases from Enable

Natural Gas Expenses [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]

Natural gas expenses, including transportation and storage costs (1)

^[8]

Accounts payable for natural gas purchases from Enable

$ 9

$ 11

Limited partner ownership interest

^[2]

100.00%

Maximum incentive distribution right

50.00%

Enable Midstream Partners [Member] | OGE [Member]

Limited partner ownership interest

^[2]

25.50%

Enable Midstream Partners [Member] | Public unitholders [Member]

Limited partner ownership interest

^[2]

20.80%

Enable Midstream Partners [Member] | Minimum [Member]

Incentive distribution per unit

$ 0.2875

Enable Midstream Partners [Member] | Maximum [Member]

Incentive distribution per unit

$ 0.330625

Enable Midstream Partners [Member] | Common Units [Member]

Enable Midstream Partners [Member] | Common Units [Member] | OGE [Member]

^[5]

435,150,159

Enable Midstream Partners [Member] | Common Units [Member] | Public unitholders [Member]

^[5]

110,982,805

Enable GP, LLC [Member] | CenterPoint Energy [Member]

^[5]

90,310,731

Management rights ownership percentage

^[9],[10]

50.00%

Incentive distribution right

^[10],[11]

40.00%

Enable GP, LLC [Member] | OGE [Member]

Management rights ownership percentage

^[9]

50.00%

Incentive distribution right

^[11]

60.00%

Enable Midstream Partners [Member] | Discontinued Operations, Disposed of by Means Other than Sale, Spinoff [Member] | CERC Corp [Member]

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Equity in earnings of unconsolidated affiliate, net

184

Income tax expense

Income from discontinued operations (net of tax of $-0-, $13, $-0- and $44, respectively)

$ 44

$ 140

Subsequent Event [Member] | Enable Midstream Partners [Member]

Enable's common unit price

$ 10.07

Amount below carrying value

$ 112

[1]	Represents the equity investment in ProLiance Holdings, LLC related primarily to an investment in LA Storage, LLC, a joint venture in a development project for salt-cavern natural gas storage, which was acquired in the Merger. This presentation reflects preliminary fair value of the equity investment on the acquisition date and is subject to change. See Note 3.
[2]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[3]	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 original investment in Enable and its underlying equity in net assets of Enable. The basis difference is being amortized through the year 2048.
[4]	Prior to the Internal Spin in September 2018, distributions from Enable were received by CERC. After such date, distributions from Enable were received by CenterPoint Energy.
[5]	Held indirectly through CNP Midstream by CenterPoint Energy.
[6]	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of September 30, 2019 and $363 million as of December 31, 2018. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods.
[7]	Represents amounts billed for certain support services provided to Enable. Actual support services costs are recorded net of reimbursement.
[8]	Included in Non-utility costs of revenues, including natural gas on CenterPoint Energy’s and CERC’s respective Condensed Statements of Consolidated Income.
[9]	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.
[10]	Held indirectly through CNP Midstream.
[11]	Enable is expected to pay a minimum quarterly distribution of $0.2875 per common unit on its outstanding common units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to Enable GP and its affiliates, within 60 days after the end of each quarter. If cash distributions to Enable’s unitholders exceed $0.330625 per common unit in any quarter, Enable GP will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances Enable GP will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election. To date, no incentive distributions have been made.

Goodwill and Other Intangibles (CenterPoint Energy and CERC) (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

$ 5,179

$ 867

^[1]

4,312

436

106

(80)

(41)

356

Finite-Lived Intangible Assets Amortization Expense Maturity Schedule [Abstract]

$ 0

Indiana Electric Integrated [Member]

1,008

^[1]

1,008

3,275

746

^[1]

2,529

Accumulated goodwill impairment charge recorded in 2012

^[2]

110

252

Infrastructure Services [Member]

355

Corporate and Other [Member]

^[1]

355

431

Customer Relationships [Member]

^[1]

420

306

^[3]

306

^[3]

(40)

^[3]

(40)

^[3]

(27)

Noncompete Agreements [Member]

266

^[3]

266

^[3]

(3)

Trade Names [Member]

^[3]

(4)

^[3]

(4)

^[3]

Construction Backlog [Member]

^[3]

^[3],[4]

(18)

^[3],[4]

(18)

^[3],[4]

Operation and maintenance agreements [Member]

^[3],[4]

^[3],[4]

(1)

^[3],[4]

(1)

^[3],[4]

^[3],[4]

Other [Member]

^[3]

^[3]

(14)

(11)

^[3]

867

106

(48)

(41)

Finite-Lived Intangible Assets Amortization Expense Maturity Schedule [Abstract]

CERC Corp [Member] | Natural Gas Distribution [Member]

CERC Corp [Member] | Energy Services [Member]

746

Accumulated goodwill impairment charge recorded in 2012

110

^[5]

110

^[5]

110

252

CERC Corp [Member] | Corporate and Other [Member]

CERC Corp [Member] | Customer Relationships [Member]

(31)

(27)

CERC Corp [Member] | Noncompete Agreements [Member]

(3)

CERC Corp [Member] | Other [Member]

(14)

(11)

Depreciation and amortization expense [Member]

$ 5

Depreciation and amortization expense [Member] | CERC Corp [Member]

^[6]

$ 2

Non-utility cost of revenues [Member]

^[7]

$ 0

^[7]

$ 0

Vectren [Member] | Depreciation and amortization expense [Member]

$ 4,306

4,306

^[6]

$ 13

[1]	The allocation of goodwill to reportable segments subsequent to the Merger is preliminary and subject to change. See Note 3.
[2]	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.
[3]	The fair value of intangible assets acquired through acquisitions is preliminary and subject to change. See Note 3.
[4]	Amortization expense related to the operation and maintenance agreements and construction backlog is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Condensed Statements of Consolidated Income.
[5]	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.
[6]	Includes $5 million and $13 million for the three and nine months ended September 30, 2019, respectively, of amortization expense related to intangibles acquired in the Merger. The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.
[7]	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
TargetAnnualYieldOnReferenceShares	2.309%
Subordinated Debt ZENS [Member]
Principal amount of debt issued	$ 1,000
Outstanding debt balance	$ 828
Subordinated note cash exchangeable percentage of fair value	95.00%
Debt Instrument, Interest Rate, Stated Percentage	2.00%
Contingent principal amount outstanding	$ 80
AT&T Common [Member]
Balance of investment owned (in shares)	10,212,945	10,212,945
AT&T Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note	0.7185	0.7185
Charter Common [Member]
Balance of investment owned (in shares)	872,503	872,912
Charter Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note	0.061382	0.061382

Short-Term Borrowings and Long-term Debt (Details)
$ in Millions

9 Months Ended

Sep. 30, 2019

USD ($)

day

Aug. 12, 2019

USD ($)

May 15, 2019

USD ($)

Feb. 08, 2019

USD ($)

^[14]

Jan. 15, 2019

USD ($)

Dec. 31, 2018

USD ($)

Commercial paper issued in connection with the Merger

Accrued interest expense

$ 5

$ 764

Number of days until commercial paper maturity | day

Number of days until commercial paper maturity | day

$ 5,100

VCC [Member]

Credit facility swing line sublimit

^[1]

$ 200

Letters of credit swing line sublimit

Parent Company [Member]

3,300

VUHI [Member]

Credit facility swing line sublimit

^[2]

400

Letters of credit swing line sublimit

1,708

General mortgage bonds used as collateral

$ 68

300

VUHI [Member]

Intercompany notes payable established as a result of the merger

$ 568

Number of days until commercial paper maturity | day

Number of days until commercial paper maturity | day

VCC [Member]

Intercompany notes payable established as a result of the merger

$ 191

70.00%

70.00%

Revolving Credit Facility [Member]

$ 900

Revolving Credit Facility [Member] | VCC [Member]

Revolving Credit Facility [Member] | Parent Company [Member]

^[3]

Revolving Credit Facility [Member] | VUHI [Member]

^[4]

Revolving Credit Facility [Member] | Houston Electric [Member]

^[5]

Revolving Credit Facility [Member] | CERC Corp [Member]

Line of Credit [Member] | VCC [Member]

$ 0

Percentage on limitation of debt to total capitalization under covenant

^[1]

65.00%

Line of Credit [Member] | VCC [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[1],[6]

0.571

^[1],[7]

1.25%

Line of Credit [Member] | Parent Company [Member]

^[1],[7]

1.25%

Percentage on limitation of debt to total capitalization under covenant

^[8]

65.00%

Percentage on limitation of debt to total capitalization under covenant amended (in hundredths)

70.00%

System restoration costs threshold for increase in permitted debt to EBITDA covenant ratio

^[6]

0.586

$ 100

Consecutive period for system restoration costs to exceed $100 million (in months)

Line of Credit [Member] | Parent Company [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[7]

1.50%

Line of Credit [Member] | VUHI [Member]

^[7]

1.50%

Percentage on limitation of debt to total capitalization under covenant

^[2]

65.00%

Line of Credit [Member] | VUHI [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[2],[6]

0.529

^[2],[7]

1.125%

Line of Credit [Member] | Houston Electric [Member]

^[2],[7]

1.125%

Percentage on limitation of debt to total capitalization under covenant

^[8]

65.00%

Line of Credit [Member] | Houston Electric [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[6]

0.487

^[7]

1.125%

Line of Credit [Member] | CERC Corp [Member]

^[7]

1.125%

Percentage on limitation of debt to total capitalization under covenant

65.00%

Line of Credit [Member] | CERC Corp [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[6]

0.475

^[7]

1.25%

Letter of Credit [Member]

^[7]

1.25%

Letter of Credit [Member] | VCC [Member]

$ 7

Letter of Credit [Member] | Parent Company [Member]

^[3]

Letter of Credit [Member] | VUHI [Member]

^[4]

Letter of Credit [Member] | SIGECO [Member]

^[5]

Letter of Credit [Member] | Houston Electric [Member]

Letter of Credit [Member] | CERC Corp [Member]

Commercial Paper [Member]

Commercial Paper [Member] | VCC [Member]

1,971

210

^[3]

$ 0

Commercial Paper [Member] | Parent Company [Member]

^[3]

0.00%

^[4]

$ 1,383

$ 0

Commercial Paper [Member] | VUHI [Member]

^[4]

2.28%

0.00%

^[5]

$ 278

Commercial Paper [Member] | Houston Electric [Member]

^[5]

2.30%

Commercial Paper [Member] | CERC Corp [Member]

$ 0

$ 310

$ 210

Long term Debt Excluding ZENS [Member]

2.28%

2.93%

Maturities of Long-term Debt [Abstract]

General Mortgage Bonds Due 2049 [Member] | Houston Electric [Member]

$ 69

831

2,761

2,998

713

1,184

$ 6,447

$ 700

4.25%

Revolving Credit Facility [Member] | Vectren [Member]

4.25%

Variable term rate loan 2 [Member]

^[9]

$ 0

2.81%

Variable term rate loan 2 [Member] | Vectren [Member]

2.81%

First Mortgage Bonds [Member] | Vectren [Member]

^[10]

$ 200

Commercial Paper [Member] | Vectren [Member]

^[11]

293

Senior Notes Due Range 2 [Member] | Vectren [Member]

^[12]

278

Senior Notes Due Range 2 [Member] | VUHI [Member]

^[13]

637

Senior Notes Due Range 2 [Member] | Indiana Gas [Member]

532

Senior Notes Due Range 2 [Member] | VCC [Member]

Variable rate term loan [Member]

$ 9

$ 1,000

$ 25

^[14]

2.88%

Variable rate term loan [Member] | Vectren [Member]

^[14]

2.88%

Senior Notes Due 2024 [Member] | Parent Company [Member]

^[15]

$ 300

$ 500

2.50%

Senior Notes Due 2030 [Member]

2.50%

2.95%

Senior Notes Due 2030 [Member] | Parent Company [Member]

2.95%

Senior Notes Due 2049 [Member]

$ 400

3.70%

Senior Notes Due 2049 [Member] | Parent Company [Member]

3.70%

Minimum [Member] | VUHI [Member]

$ 300

70.00%

Minimum [Member] | First Mortgage Bonds [Member] | Vectren [Member]

70.00%

2.375%

Minimum [Member] | Senior Notes Due Range 2 [Member] | Vectren [Member]

2.375%

3.33%

Maximum [Member] | VUHI [Member]

3.33%

90.00%

Maximum [Member] | Letter of Credit [Member] | Vectren [Member]

90.00%

Maximum [Member] | First Mortgage Bonds [Member] | Vectren [Member]

$ 50

6.72%

Maximum [Member] | Senior Notes Due Range 2 [Member] | Vectren [Member]

6.72%

7.08%

7.08%

[1]	This credit facility was issued by VCC, is guaranteed by Vectren and includes a $40 million swing line sublimit and an $80 million letter of credit sublimit.
[2]	This credit facility was issued by VUHI, is guaranteed by SIGECO, Indiana Gas and VEDO and includes a $10 million swing line sublimit and a $20 million letter of credit sublimit. This credit facility backstops VUHI’s commercial paper program.
[3]	This credit facility was issued by VCC and is guaranteed by Vectren.
[4]	CenterPoint Energy’s outstanding commercial paper generally has maturities of 60 days or less.
[5]	This credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.
[6]	As defined in the revolving credit facility agreements, excluding Securitization Bonds.
[7]	Based on current credit ratings.
[8]	For CenterPoint Energy and Houston Electric, the financial covenant limit will temporarily increase from 65% 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.
[9]	Represents borrowings under the VCC credit facility, which is guaranteed by Vectren.
[10]	Issued by VCC and guaranteed by Vectren. As of September 30, 2019, the term loan was fully drawn upon, exclusive of any potential incremental term loans under the related facility’s accordion feature. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread of 70 basis points.
[11]	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture. The first mortgage bonds have stated interest rates that range from 2.375% to 6.72%.
[12]	Issued by VUHI with maturities up to 30 days.
[13]	Consists of $532 million of senior notes issued by VUHI, $96 million of senior notes issued by Indiana Gas, and $9 million of senior notes issued by VCC. The senior notes have stated interest rates that range from 3.33% to 7.08%. The senior notes issued by VUHI are guaranteed by SIGECO, Indiana Gas and VEDO. The senior notes issued by VCC are guaranteed by Vectren. In connection with the Merger, two of CenterPoint Energy’s acquired wholly-owned subsidiaries, VUHI and VCC, made offers to prepay certain outstanding guaranteed senior notes as required pursuant to certain note purchase agreements previously entered into by VUHI and VCC. In turn, VUHI and VCC borrowed $568 million and $191 million, respectively, from CenterPoint Energy to fund note redemptions effected pursuant to these prepayment offers. To fund these prepayments and payments of approximately $5 million of accrued interest, CenterPoint Energy issued approximately $764 million of commercial paper.
[14]	Draw down by VCC on its variable rate term loan.
[15]	Issued by VUHI and guaranteed by SIGECO, Indiana Gas and VEDO. As of September 30, 2019, the term loan was fully drawn upon. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread ranging from 70 to 90 basis points depending on credit rating.

Income Taxes (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Net uncertain tax liability

^[1]

19.00%

24.00%

15.00%

26.00%

$ 1

Continuing Operations [Member] | CERC Corp [Member]

^[2]

18.00%

20.00%

18.00%

21.00%

Discontinued Operations [Member] | CERC Corp [Member]

^[3],[4]

13.00%

5.00%

14.00%

29.00%

Federal statutory tax rate

^[5]

23.00%

24.00%

^[5]

21.00%

[1]	CenterPoint Energy’s lower effective tax rate for the three and nine months ended September 30, 2019 compared to the same periods for 2018 was primarily due to the following: an increase in the amount of amortization of the net regulatory EDIT liability; the effect of state tax law changes that resulted in the remeasurement of state deferred taxes; and the impact of changes in valuation allowances on certain state net operating losses.
[2]	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2019 compared to the same periods for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability.
[3]	CERC’s higher effective tax rate on loss from continuing operations for the three months ended September 30, 2019 compared to the same period for 2018 was primarily due to a decrease in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the absence of a change in the valuation allowance on certain state net operating losses in the three months ended September 30, 2019, the effects of which are compounded by the book loss in the three months ended September 30, 2019.
[4]	CERC’s lower effective tax rate on income from continuing operations for the nine months ended September 30, 2019 compared to the same period for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the impact of changes in the valuation allowances on certain state net operating losses in 2019.
[5]	CERC’s effective tax rate on income from discontinued operations for the three and nine months ended September 30, 2018 was a result of the 21% federal income tax rate plus allocable state income taxes. There are no comparable periods in 2019 since the Internal Spin was completed in the third quarter of 2018.

Commitments and Contingencies (Details)	9 Months Ended
Commitments and Contingencies (Details)	Sep. 30, 2019 USD ($) site
Purchase Obligations
Remaining three months of 2019	$ 217,000,000
2020	745,000,000
2021	614,000,000
2022	412,000,000
2023	330,000,000
2024	265,000,000
2025 and beyond	$ 1,846,000,000
Performance Guarantees & Product Warranties [Abstract]
Number of surety bond obligations outstanding	63
Performance guarantee obligations outstanding face amount	$ 627,000,000
Percentage of work yet to be completed on projects with open surety bonds	35.00%
Guarantor obligations, maximum exposure, undiscounted	$ 498,000,000
Legal, Environmental and Other Matters
Asset retirement obligation	75,000,000
Minimum [Member]
Legal, Environmental and Other Matters
Estimated capital expenditure to clean ash ponds	60,000,000
Maximum [Member]
Legal, Environmental and Other Matters
Estimated capital expenditure to clean ash ponds	80,000,000
Minnesota Service Territory [Member]
Legal, Environmental and Other Matters
Liability recorded for environmental loss contingencies	9,000,000
Minnesota Service Territory [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 7,000,000
Years to resolve contingency	5 years
Minnesota Service Territory [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 51,000,000
Years to resolve contingency	50 years
Indiana Gas Service Territory [Member]
Legal, Environmental and Other Matters
Environmental remediation number of sites with potential remedial responsibility \| site	26
CERC Corp [Member]
Purchase Obligations
Remaining three months of 2019	$ 160,000,000
2020	528,000,000
2021	429,000,000
2022	235,000,000
2023	177,000,000
2024	169,000,000
2025 and beyond	1,483,000,000
CERC Corp [Member] \| Minnesota Service Territory [Member]
Legal, Environmental and Other Matters
Liability recorded for environmental loss contingencies	7,000,000
CERC Corp [Member] \| Minnesota Service Territory [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 4,000,000
Years to resolve contingency	30 years
CERC Corp [Member] \| Minnesota Service Territory [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 32,000,000
Years to resolve contingency	50 years
Minnehaha Academy Gas Explosion [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000
Minnehaha Academy Gas Explosion [Member] \| CERC Corp [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000

Earnings Per Share (CenterPoint Energy) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Preferred Stock Dividends, Income Statement Impact

$ 29

$ 5

$ 88

$ 5

Numerator:

Income available to common shareholders - basic

241

153

546

243

Net Income (Loss) Available to Common Stockholders, Diluted

$ 241

$ 153

$ 546

$ 243

Denominator:

Weighted average common shares outstanding - basic

502,228,000

431,554,000

501,986,000

431,437,000

Weighted average common shares outstanding - diluted

505,080,000

434,891,000

504,838,000

434,774,000

Earnings per common share:

Basic earnings per common share

$ 0.48

$ 0.35

$ 1.09

$ 0.56

Diluted earnings per common share

$ 0.47

$ 0.35

$ 1.08

$ 0.56

Restricted Stock [Member]

Denominator:

Restricted stock

2,852,000

3,337,000

2,852,000

3,337,000

Series B Preferred Stock [Member]

Preferred Stock Dividends, Income Statement Impact

$ 17

$ 0

$ 51

$ 0

Numerator:

Series B Preferred Stock (1)

$ 0

Denominator:

^[1]

Earnings per common share:

Amount of antidilutive shares excluded from computation of earnings per share

33,537,000

[1]

Reportable Business Segments (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

$ 2,742

$ 2,212

$ 9,071

$ 7,553

Equity in earnings from investment in Enable

392

226

924

664

213

208

34,642

$ 27,009

Houston Electric T&D [Member]

2,212

2,044

^[1]

859

897

2,313

2,502

Houston Electric T&D [Member] | Affiliates of NRG Energy, Inc. [Member]

269

227

522

523

Houston Electric T&D [Member] | Affiliates of Vistra Energy Corp. [Member]

231

213

547

543

Indiana Electric Integrated [Member]

196

192

165

388

515

402

2,554

2,032

241

166

734

910

2,754

3,008

Infrastructure Services [Member]

(9)

(20)

376

847

Midstream Investments [Member]

^[2]

Equity in earnings from investment in Enable

^[2]

213

208

Corporate and Other [Member]

215

Intersegment Eliminations [Member]

(17)

(5)

(21)

(18)

(123)

(83)

Intersegment Eliminations [Member] | Houston Electric T&D [Member]

(3,026)

(652)

Intersegment Eliminations [Member] | Indiana Electric Integrated [Member]

Intersegment Eliminations [Member] | Natural Gas Distribution [Member]

Intersegment Eliminations [Member] | Energy Services [Member]

(9)

(8)

(29)

(26)

Intersegment Eliminations [Member] | Infrastructure Services [Member]

(11)

(10)

(92)

(57)

Intersegment Eliminations [Member] | Midstream Investments [Member]

(1)

(2)

Intersegment Eliminations [Member] | Corporate and Other [Member]

^[2]

Operating Segments [Member] | Houston Electric T&D [Member]

Operating Segments [Member] | Indiana Electric Integrated [Member]

11,463

10,509

Operating Segments [Member] | Natural Gas Distribution [Member]

^[3]

3,009

Operating Segments [Member] | Energy Services [Member]

13,235

^[3]

13,235

^[3]

6,956

Operating Segments [Member] | Infrastructure Services [Member]

1,264

1,558

Operating Segments [Member] | Midstream Investments [Member]

^[3]

1,284

Operating Segments [Member] | Corporate and Other [Member]

2,529

2,482

Pension and Other Postretirement Plans Costs [Member] | Corporate and Other [Member]

^[4]

4,884

^[3]

4,884

^[3]

6,156

625

665

859

897

2,310

2,506

269

227

519

527

11,463

10,507

Houston Electric [Member] | Houston Electric T&D [Member] | Affiliates of NRG Energy, Inc. [Member]

951

1,124

Houston Electric [Member] | Houston Electric T&D [Member] | Affiliates of Vistra Energy Corp. [Member]

231

213

547

543

196

192

1,126

1,312

4,836

5,040

(7)

277

146

7,929

8,214

CERC Corp [Member] | Natural Gas Distribution [Member]

207

258

389

402

2,077

2,032

CERC Corp [Member] | Energy Services [Member]

212

166

734

910

2,755

3,008

CERC Corp [Member] | Corporate and Other [Member]

(9)

(20)

CERC Corp [Member] | Intersegment Eliminations [Member]

(1)

(20)

(18)

(120)

(83)

CERC Corp [Member] | Intersegment Eliminations [Member] | Natural Gas Distribution [Member]

(474)

(366)

CERC Corp [Member] | Intersegment Eliminations [Member] | Energy Services [Member]

(9)

(8)

(29)

(26)

CERC Corp [Member] | Intersegment Eliminations [Member] | Corporate and Other [Member]

(11)

(10)

(91)

(57)

CERC Corp [Member] | Operating Segments [Member] | Natural Gas Distribution [Member]

$ 0

CERC Corp [Member] | Operating Segments [Member] | Energy Services [Member]

7,018

6,956

CERC Corp [Member] | Operating Segments [Member] | Corporate and Other [Member]

1,264

1,558

Cash and Cash Equivalents [Member]

^[3]

$ 121

Interest, net of capitalized interest

Short-term Investments

$ 3,900

[1]

Houston Electric T&D revenues from major external customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Affiliates of NRG	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	83		79		196		192

[2]

CenterPoint Energy’s Midstream Investments’ equity in earnings, net are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Enable	$	77	$	81	$	213	$	208

[3]

Total assets by reportable segment include assets acquired in the Merger, which are based on preliminary fair value estimates and allocations on the acquisition date and are subject to change. See Note 3.

[4]

Supplemental Disclosure of Cash Flow Information (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

Dec. 31, 2017

$ 364

$ 301

Income taxes, net

174

Accounts payable related to capital expenditures

178

140

ROU assets obtained in exchange for lease liabilities (1)

^[1]

Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows

$ 259

259

$ 4,231

297

$ 331

297

331

4,278

$ 296

Prepaid expenses and other current assets [Member]

Other [Member]

Interest, net of capitalized interest

203

173

Income taxes, net

122

Accounts payable related to capital expenditures

ROU assets obtained in exchange for lease liabilities (1)

^[1]

Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows

228

335

247

317

247

317

370

274

Houston Electric [Member] | Prepaid expenses and other current assets [Member]

Houston Electric [Member] | Other [Member]

Interest, net of capitalized interest

Income taxes, net

Accounts payable related to capital expenditures

Capital distribution to parent associated with the Internal Spin

1,460

ROU assets obtained in exchange for lease liabilities (1)

^[1]

Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows

$ 1

$ 12

CERC Corp [Member] | Prepaid expenses and other current assets [Member]

CERC Corp [Member] | Other [Member]

$ 0

[1]	Includes the transition impact of adoption of ASU 2016-02 Leases.

Related Party Transactions (Houston Electric and CERC) (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Sep. 30, 2018

Sep. 30, 2019

Sep. 30, 2018

Dec. 31, 2018

Interest income (expense) (1)

^[1]

$ 5

$ 1

$ 14

$ 1

Cash dividends paid to parent

100

123

Cash contribution from parent

590

Houston Electric [Member] | Operation and maintenance expense [Member]

Net affiliate service charges (billings)

(3)

(7)

(8)

Houston Electric [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]

Corporate service charges

132

138

Interest income (expense) (1)

^[1]

(2)

(4)

Cash dividends paid to parent

119

286

Cash contribution from parent

600

Capital distribution to parent associated with the Internal Spin

1,460

CERC Corp [Member] | Operation and maintenance expense [Member]

Net affiliate service charges (billings)

CERC Corp [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]

Corporate service charges

$ 31

$ 36

$ 106

$ 105

Investments [Member] | Houston Electric [Member]

Weighted average interest rate

2.32%

2.42%

Investments [Member] | CERC Corp [Member]

Weighted average interest rate

2.32%

2.42%

Accounts and notes receivable (payable) - affiliate companies [Member] | Houston Electric [Member]

Money pool investments (borrowings) (1)

^[2]

$ 772

Money Pool Borrowings

^[2]

$ (1)

Accounts and notes receivable (payable) - affiliate companies [Member] | CERC Corp [Member]

Money pool investments (borrowings) (1)

^[2]

$ 87

$ 114

[1]	Interest income is included in Other income (expense), net and interest expense is included in Interest and other finance charges on Houston Electric’s and CERC’s respective Condensed Statements of Consolidated Income.
[2]	Included in Accounts and notes receivable (payable)–affiliated companies on Houston Electric’s and CERC’s respective Condensed Consolidated Balance Sheets.

Leases (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Jan. 01, 2019

Dec. 31, 2018

Lease, Cost [Abstract]

Operating lease cost

$ 8

$ 19

Short-term lease cost

Variable lease cost

Total lease cost

Assets and Liabilities, Lessee [Abstract]

Operating ROU assets (1)

^[1]

Lease Right-Of-Use Asset

$ 30

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

$ 46

Weighted-average remaining lease term (in years) - operating leases

5 years 2 months 12 days

Weighted-average discount rate - operating leases

3.41%

Operating Lease Liabilities, Payments Due [Abstract]

Present value of lease liabilities

$ 6

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

Operating Leases, Future Minimum Payments Due, Next Twelve Months

$ 6

Operating Leases, Future Minimum Payments, Due in Two Years

Operating Leases, Future Minimum Payments, Due in Three Years

Operating Leases, Future Minimum Payments, Due in Four Years

Operating Leases, Future Minimum Payments, Due in Five Years

Operating Leases, Future Minimum Payments, Due Thereafter

Operating Leases, Future Minimum Payments Due

^[4]

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Lessor, Operating Lease, Payments to be Received, Remainder of Fiscal Year

Lessor, Operating Lease, Payments to be Received, Next Twelve Months

Lessor, Operating Lease, Payments to be Received, Two Years

Lessor, Operating Lease, Payments to be Received, Three Years

Lessor, Operating Lease, Payments to be Received, Four Years

Lessor, Operating Lease, Payments to be Received, Five Years

Lessor, Operating Lease, Payments to be Received, Thereafter

Lessor, Operating Lease, Payments to be Received

Other Information Related to Leases [Abstract]

Lessee Operating Lease Not Yet Commenced

Operating Lease, Payments

Assets and Liabilities, Lessee [Abstract]

Lease, Cost [Abstract]

Operating lease cost

Short-term lease cost

Variable lease cost

Total lease cost

Operating ROU assets (1)

^[1]

Lease Right-Of-Use Asset

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

$ 1

Weighted-average remaining lease term (in years) - operating leases

5 years 4 months 24 days

Weighted-average discount rate - operating leases

3.51%

Operating Lease Liabilities, Payments Due [Abstract]

Present value of lease liabilities

$ 0

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

Operating Leases, Future Minimum Payments Due, Next Twelve Months

Operating Leases, Future Minimum Payments, Due in Two Years

Operating Leases, Future Minimum Payments, Due in Three Years

Operating Leases, Future Minimum Payments, Due in Four Years

Operating Leases, Future Minimum Payments, Due in Five Years

Operating Leases, Future Minimum Payments, Due Thereafter

Operating Leases, Future Minimum Payments Due

^[4]

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Lessor, Operating Lease, Payments to be Received, Remainder of Fiscal Year

Lessor, Operating Lease, Payments to be Received, Next Twelve Months

Lessor, Operating Lease, Payments to be Received, Two Years

Lessor, Operating Lease, Payments to be Received, Three Years

Lessor, Operating Lease, Payments to be Received, Four Years

Lessor, Operating Lease, Payments to be Received, Five Years

Lessor, Operating Lease, Payments to be Received, Thereafter

Lessor, Operating Lease, Payments to be Received

Other Information Related to Leases [Abstract]

Operating Lease, Payments

Assets and Liabilities, Lessee [Abstract]

Lease, Cost [Abstract]

Operating lease cost

Short-term lease cost

Variable lease cost

Total lease cost

Operating ROU assets (1)

^[1]

Lease Right-Of-Use Asset

$ 27

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

$ 21

Weighted-average remaining lease term (in years) - operating leases

7 years 10 months 24 days

Weighted-average discount rate - operating leases

3.66%

Operating Lease Liabilities, Payments Due [Abstract]

Present value of lease liabilities

$ 1

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

Operating Leases, Future Minimum Payments Due, Next Twelve Months

Operating Leases, Future Minimum Payments, Due in Two Years

Operating Leases, Future Minimum Payments, Due in Three Years

Operating Leases, Future Minimum Payments, Due in Four Years

Operating Leases, Future Minimum Payments, Due in Five Years

Operating Leases, Future Minimum Payments, Due Thereafter

Operating Leases, Future Minimum Payments Due

^[4]

$ 32

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Lessor, Operating Lease, Payments to be Received, Remainder of Fiscal Year

Lessor, Operating Lease, Payments to be Received, Next Twelve Months

Lessor, Operating Lease, Payments to be Received, Two Years

Lessor, Operating Lease, Payments to be Received, Three Years

Lessor, Operating Lease, Payments to be Received, Four Years

Lessor, Operating Lease, Payments to be Received, Five Years

Lessor, Operating Lease, Payments to be Received, Thereafter

Lessor, Operating Lease, Payments to be Received

Other Information Related to Leases [Abstract]

Operating Lease, Payments

$ 2

$ 4

[1]	Reported within Other assets in the Condensed Consolidated Balance Sheets.
[2]	Reported within Current other liabilities in the Condensed Consolidated Balance Sheets.
[3]	Reported within Other liabilities in the Condensed Consolidated Balance Sheets.
[4]	The Merger was completed on February 1, 2019. As such, these amounts are exclusive of Vectren’s leases.

Equity (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Sep. 30, 2019

Sep. 30, 2018

$ 0.2875

$ 0.2775

$ 0.5750

$ 0.5550

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

$ 29

$ 5

$ 88

$ 5

Beginning Balance

(105)

$ (108)

(62)

$ (68)

(108)

(68)

Other comprehensive loss from unconsolidated affiliates, net of tax

(2)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax

^[1]

Actuarial losses

^[1]

Reclassification of deferred loss from cash flow hedges realized in net income

Tax expense

(2)

(4)

Net current period other comprehensive income (loss)

(2)

Ending Balance

$ (107)

$ (105)

$ (58)

$ (62)

$ (107)

$ (58)

Common Stock [Member]

$ 0.2875

$ 0.2775

$ 0.2875

$ 0.2775

$ 0.8625

$ 0.8325

Series A Preferred Stock [Member]

$ 433

$ 360

Preferred stock dividends declared

$ 30.6250

$ 0.0000

$ 30.6250

$ 0.0000

$ 62.7813

$ 50

Series B Preferred Stock [Member]

$ 12

$ 5

$ 37

$ 5

Preferred stock dividends declared

$ 17.5000

$ 0.0000

$ 35.0000

$ 0.0000

$ 52.5000

$ 51

$ 17

$ 0

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Beginning Balance

(15)

(14)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax

^[1]

Actuarial losses

^[1]

Reclassification of deferred loss from cash flow hedges realized in net income

Tax expense

(1)

Net current period other comprehensive income (loss)

(1)

Ending Balance

(15)

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Beginning Balance

$ 5

$ 6

Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax

^[1]

Actuarial losses

^[1]

Reclassification of deferred loss from cash flow hedges realized in net income

Tax expense

Net current period other comprehensive income (loss)

Ending Balance

$ 5

$ 6

Interest Rate Contract [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications

^[2]

(2)

(3)

Interest Rate Contract [Member] | Houston Electric [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications

^[2]

(1)

Interest Rate Contract [Member] | CERC Corp [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications

^[2]

$ 0

First Quarter 2019 [Member] | Common Stock [Member]

Dec. 12, 2018

Feb. 21, 2019

Mar. 14, 2019

$ 0.2875

First Quarter 2019 [Member] | Series A Preferred Stock [Member]

$ 144

Dec. 12, 2018

Feb. 15, 2019

Mar. 01, 2019

$ 32.1563

First Quarter 2019 [Member] | Series B Preferred Stock [Member]

$ 26

Dec. 12, 2018

Feb. 15, 2019

Mar. 01, 2019

$ 17.5000

Second Quarter 2019 [Member] | Common Stock [Member]

$ 17

Apr. 25, 2019

May 16, 2019

Jun. 13, 2019

$ 0.2875

Second Quarter 2019 [Member] | Series B Preferred Stock [Member]

$ 144

Jul. 31, 2019

Apr. 25, 2019

Aug. 15, 2019

May 15, 2019

Sep. 03, 2019

Jun. 03, 2019

$ 17.5000

Third Quarter 2019 [Member] | Common Stock [Member]

$ 17

Jul. 31, 2019

Aug. 15, 2019

Sep. 12, 2019

$ 0.2875

Third Quarter 2019 [Member] | Series A Preferred Stock [Member]

$ 145

Jul. 31, 2019

Aug. 15, 2019

Sep. 03, 2019

$ 30.6250

First Quarter 2018 [Member] | Common Stock [Member]

$ 24

Dec. 13, 2017

Feb. 15, 2018

Mar. 08, 2018

$ 0.2775

Second Quarter 2018 [Member] | Common Stock [Member]

$ 120

Apr. 26, 2018

May 17, 2018

Jun. 14, 2018

$ 0.2775

Third Quarter 2018 [Member] | Common Stock [Member]

$ 120

Jul. 26, 2018

Aug. 16, 2018

Sep. 13, 2018