View Filing Data

Utility natural gas, fuel and purchased power

12,301

10,589

9,614

Expenses:

1,683

1,410

1,109

Non-utility cost of revenues, including natural gas

^[1]

4,029

4,364

3,785

Operation and maintenance

3,550

2,335

2,157

Taxes other than income taxes

1,287

1,243

1,036

478

406

391

Gain (loss) on marketable securities

11,075

9,758

8,478

Operating Income

1,226

831

1,136

Other Income (Expense):

282

(22)

Gain (loss) on indexed debt securities

(292)

(232)

Interest and other finance charges

(528)

(361)

(313)

Interest on Securitization Bonds

(39)

(59)

(77)

Equity in earnings of unconsolidated affiliates, net

230

307

265

(4)

Income Before Income Taxes

(297)

(317)

(73)

929

514

1,063

Income tax expense (benefit)

138

146

(729)

Net Income

791

368

1,792

Income Available to Common Shareholders

117

^[2]

$ 674

$ 333

$ 1,792

Basic Earnings Per Common Share

$ 1.34

$ 0.74

$ 4.16

Diluted Earnings Per Common Share

$ 1.33

$ 0.74

$ 4.13

Weighted Average Common Shares Outstanding, Basic

502,050,000

448,829,000

430,964,000

Weighted Average Common Shares Outstanding, Diluted

505,157,000

452,465,000

434,308,000

Revenues:

Operation and maintenance

$ 2,990

$ 3,234

$ 2,998

Expenses:

1,477

1,452

1,402

Taxes other than income taxes

648

917

724

247

240

235

Interest and other finance charges

2,372

2,609

2,361

Operating Income

618

625

637

Other Income (Expense):

(164)

(138)

(128)

Interest on Securitization Bonds

(39)

(59)

(77)

(3)

(8)

Income Before Income Taxes

(182)

(200)

(213)

436

425

424

Income tax expense (benefit)

(9)

Net Income

356

336

433

Revenues:

Utility revenues

2,911

2,931

2,606

Non-utility revenues

3,659

4,412

3,997

Utility natural gas, fuel and purchased power

6,570

7,343

6,603

Expenses:

1,312

1,410

1,109

Non-utility cost of revenues, including natural gas

^[1]

3,503

4,364

3,785

Operation and maintenance

890

898

816

Taxes other than income taxes

305

293

279

162

156

147

Interest and other finance charges

6,220

7,121

6,136

Operating Income

350

222

467

Other Income (Expense):

(116)

(122)

(123)

(8)

(25)

Income Before Income Taxes

(124)

(130)

(148)

226

319

Income tax expense (benefit)

(265)

Income From Continuing Operations

212

584

Income from discontinued operations (net of tax expense of $-0-, $46, and $104, respectively)

138

161

Net Income

$ 212

$ 208

$ 745

[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 the years ended December 31, 2019, 2018 and 2017, respectively.
[2]	Income available to common shareholders for the year ended December 31, 2019 includes net income from businesses acquired in the Merger of $190 million. See Note 4. Income available to common shareholders for the year ended December 31, 2017 includes a reduction in income tax expense of $1,113 million due to tax reform. See Note 15 for further discussion of the impacts of the TCJA.

STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Tax benefit (expense) on adjustment related to pension and postretirement plans	$ (4)	$ 2	$ (6)
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	(1)	(4)	(2)
Tax expense (benefit) on deferred loss from cash flow hedges realized in net income	0	0	0
Houston Electric [Member]
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	0	(4)	0
CERC Corp [Member]
Tax benefit (expense) on adjustment related to pension and postretirement plans	(2)	(1)	(4)
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	$ 0	$ 0	$ (1)

Earnings Per Share (CenterPoint Energy) (Tables)

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Basic and Diluted Earnings Per Share [Table Text Block]

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.



	For the Year Ended December 31,
	2019		2018		2017
	(in millions, except per share and share amounts)
Numerator:
Income available to common shareholders - basic (1)	$	674	$	333	$	1,792
Add back: Series B Preferred Stock dividend (2)	—		—		—
Income available to common shareholders - diluted (1)	$	674	$	333	$	1,792

Denominator:
Weighted average common shares outstanding - basic	502,050,000		448,829,000		430,964,000
Plus: Incremental shares from assumed conversions:
Restricted stock (3)	3,107,000		3,636,000		3,344,000
Series B Preferred Stock (2)	—		—		—
Weighted average common shares outstanding - diluted	505,157,000		452,465,000		434,308,000

Earnings per common share:
Basic earnings per common share	$	1.34	$	0.74	$	4.16
Diluted earnings per common share	$	1.33	$	0.74	$	4.13


(1)	Income available to common shareholders for the year ended December 31, 2019 includes net income from businesses acquired in the Merger of $190 million. See Note 4. Income available to common shareholders for the year ended December 31, 2017 includes a reduction in income tax expense of $1,113 million due to tax reform. See Note 15 for further discussion of the impacts of the TCJA.

(2)

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 year ended December 31, 2019 and December 31, 2018 excludes Series B Stock Dividends of $68 million and $17 million, respectively, and 34,354,000 and 8,885,000 potentially dilutive shares, respectively, because to include them would be anti-dilutive. However, these shares could be potentially dilutive in the future.


(3)	The potentially dilutive impact from restricted stock awards applies the treasury stock method. Under this method, an increase in the average fair market value of Common Stock can result in a greater dilutive impact from these securities.

STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows from Operating Activities:
Net income	$ 791	$ 368	$ 1,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,287	1,243	1,036
Amortization of deferred financing costs	29	48	24
Deferred income taxes	69	48	(770)
Goodwill impairment charge recorded from annual impairment test	48	0	0
Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)	24	0	0
Unrealized loss (gain) on marketable securities	(282)	22	(7)
Loss (gain) on indexed debt securities	292	232	(49)
Write-down of natural gas inventory	4	2	0
Income (Loss) from Equity Method Investments	(230)	(307)	(265)
Proceeds from Equity Method Investment, Distribution	261	267	0
Pension contributions	(109)	(69)	(48)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	226	(154)	(216)
Inventory	(52)	1	(7)
Taxes receivable	(106)	0	30
Accounts payable	(455)	220	136
Fuel cost recovery	92	33	(85)
Non-trading derivatives, net	(64)	103	(84)
Margin deposits, net	(56)	5	(55)
Interest and taxes accrued	54	40	5
Net regulatory assets and liabilities	(114)	28	(107)
Other current assets	(22)	0	(3)
Other current liabilities	(107)	(24)	34
Other assets	103	6	(4)
Other liabilities	(54)	12	36
Other, net	9	12	24
Net cash provided by operating activities	1,638	2,136	1,417
Cash Flows from Investing Activities:
Capital expenditures	(2,506)	(1,651)	(1,426)
Acquisitions, net of cash acquired	(5,991)	0	(132)
Distributions from unconsolidated affiliates in excess of cumulative earnings	42	30	297
Proceeds from sale of marketable securities	0	398	0
Proceeds from sale of assets	5	0	0
Purchase of investments	(6)	0	0
Other, net	35	16	4
Net cash provided by (used in) investing activities	(8,421)	(1,207)	(1,257)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	0	(39)	4
Proceeds from (payments of) commercial paper, net	1,891	(1,543)	349
Proceeds from long-term debt, net	2,916	2,495	1,096
Payments of long-term debt	(1,302)	(484)	(1,211)
Loss on reacquired debt	0	0	(5)
Debt and equity issuance costs	(20)	(47)	(13)
Payment of dividends on Common Stock	(577)	(499)	(461)
Payment of dividends on preferred stock	(118)	(11)	0
Proceeds from issuance of Common Stock, net	0	1,844	0
Proceeds from issuance of preferred stock, net	0	1,740	0
Distribution to ZENS holders	0	(398)	0
Other, net	(14)	(5)	(4)
Net cash provided by (used in) financing activities	2,776	3,053	(245)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(4,007)	3,982	(85)
Cash, Cash Equivalents and Restricted Cash at Beginning of Year	4,278	296	381
Cash, Cash Equivalents and Restricted Cash at End of Year	271	4,278	296
Houston Electric [Member]
Cash Flows from Operating Activities:
Net income	356	336	433
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	648	917	724
Amortization of deferred financing costs	12	11	13
Deferred income taxes	(24)	(38)	(98)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	38	11	(73)
Accounts receivable/payable–affiliated companies	(23)	20	(46)
Inventory	(12)	(16)	15
Taxes receivable	5	(5)	6
Accounts payable	13	(1)	59
Non-trading derivatives, net	(25)	5	0
Interest and taxes accrued	13	(2)	7
Net regulatory assets and liabilities	(48)	(97)	(148)
Other current assets	(5)	(2)	(6)
Other current liabilities	(9)	(26)	16
Other assets	5	(3)	13
Other liabilities	(12)	17	(4)
Other, net	(14)	(12)	(6)
Net cash provided by operating activities	918	1,115	905
Cash Flows from Investing Activities:
Capital expenditures	(1,025)	(922)	(875)
(Increase) decrease in notes receivable–affiliated companies	(481)	0	96
Other, net	11	11	3
Net cash provided by (used in) investing activities	(1,495)	(911)	(776)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	696	398	298
Payments of long-term debt	(458)	(434)	(411)
Dividend to parent	(376)	(209)	(180)
Increase (decrease) in notes payable–affiliated companies	(1)	(59)	60
Debt issuance costs	(8)	(4)	(3)
Contribution from parent	590	200	0
Other, net	(1)	0	0
Net cash provided by (used in) financing activities	442	(108)	(236)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(135)	96	(107)
Cash, Cash Equivalents and Restricted Cash at Beginning of Year	370	274	381
Cash, Cash Equivalents and Restricted Cash at End of Year	235	370	274
CERC Corp [Member]
Cash Flows from Operating Activities:
Net income	212	208	745
Income (loss) from discontinued operations, net of tax	0	138	161
Income (loss) from continuing operations	212	70	584
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	305	293	279
Amortization of deferred financing costs	9	9	9
Deferred income taxes	7	31	(224)
Goodwill impairment charge recorded from annual impairment test	48	0	0
Write-down of natural gas inventory	4	2	0
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	252	(155)	(143)
Accounts receivable/payable–affiliated companies	(6)	9	0
Inventory	(12)	17	(22)
Accounts payable	(305)	163	64
Fuel cost recovery	86	33	(85)
Non-trading derivatives, net	(60)	98	(82)
Margin deposits, net	(56)	5	(55)
Interest and taxes accrued	2	0	(41)
Net regulatory assets and liabilities	(10)	50	(27)
Other current assets	1	4	2
Other current liabilities	22	(3)	15
Other assets	5	5	(8)
Other liabilities	(38)	6	6
Other, net	0	1	6
Net cash provided by operating activities from continuing operations	466	638	278
Net cash provided by operating activities from discontinued operations	0	176	0
Net cash provided by operating activities	466	814	278
Cash Flows from Investing Activities:
Capital expenditures	(776)	(633)	(513)
Acquisitions, net of cash acquired	0	0	(132)
(Increase) decrease in notes receivable–affiliated companies	114	(114)	0
Other, net	0	3	2
Net cash used in investing activities from continuing operations	(662)	(744)	(643)
Net cash provided by investing activities from discontinued operations	0	47	297
Net cash provided by (used in) investing activities	(662)	(697)	(346)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	0	(39)	4
Proceeds from (payments of) commercial paper, net	167	(688)	329
Proceeds from long-term debt, net	0	599	298
Payments of long-term debt	0	0	(550)
Dividend to parent	(120)	(360)	(601)
Increase (decrease) in notes payable–affiliated companies	0	(570)	570
Loss on reacquired debt	0	0	(5)
Debt issuance costs	0	(5)	(4)
Contribution from parent	129	960	38
Other, net	(3)	(1)	0
Net cash used in financing activities from continuing operations	173	(104)	79
Net cash provided by financing activities from discontinued operations	0	0	0
Net cash provided by (used in) financing activities	173	(104)	79
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(23)	13	11
Cash, Cash Equivalents and Restricted Cash at Beginning of Year	25	12	1
Cash, Cash Equivalents and Restricted Cash at End of Year	$ 2	$ 25	$ 12

Regulatory Matters Regulatory Assets and Regulatory Liabilities (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Schedule of Regulatory Assets and Liabilities [Line Items]

Securitized regulatory assets

$ 788

$ 1,059

Unrecognized equity return (2)

^[1]

(168)

(213)

Unamortized loss on reacquired debt (3)

^[2]

2,117

1,967

Total regulatory assets

2,129

2,044

Total regulatory liabilities

3,474

2,525

3,521

2,563

Total regulatory assets and liabilities, net

(1,392)

(519)

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

$ 42

Prepaid Expenses and Other Current Assets [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory assets (1)

^[3]

Other Current Liabilities [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory liabilities (6)

^[4]

Amounts related to TCJA [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Schedule of Regulatory Assets and Liabilities [Line Items]

^[5]

1,582

1,323

Removal Costs [Member]

Other Regulatory Assets (Liabilities) [Member]

1,429

886

Schedule of Regulatory Assets and Liabilities [Line Items]

Pension and Other Postretirement Plans Costs [Member]

463

316

Schedule of Regulatory Assets and Liabilities [Line Items]

Amounts related to TCJA [Member]

^[2]

637

725

Schedule of Regulatory Assets and Liabilities [Line Items]

Asset Retirement Obligation Costs [Member]

^[2],[5]

Schedule of Regulatory Assets and Liabilities [Line Items]

Other Regulatory Assets (Liabilities) [Member]

^[2]

131

109

Schedule of Regulatory Assets and Liabilities [Line Items]

Remaining amounts of regulatory assets for which no return on investment during recovery period is provided

422

147

^[6]

^[2]

Hurricane Harvey [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

Securitized regulatory assets

788

1,059

Unrecognized equity return (2)

^[1]

(168)

(213)

Unamortized loss on reacquired debt (3)

^[2]

915

1,124

Total regulatory assets

915

1,124

Total regulatory liabilities

1,288

1,298

1,288

1,315

Total regulatory assets and liabilities, net

(373)

(191)

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

$ 42

Houston Electric [Member] | Prepaid Expenses and Other Current Assets [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory assets (1)

^[3]

Houston Electric [Member] | Other Current Liabilities [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory liabilities (6)

^[4]

Houston Electric [Member] | Amounts related to TCJA [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Houston Electric [Member] | Removal Costs [Member]

^[5]

821

847

Schedule of Regulatory Assets and Liabilities [Line Items]

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

244

269

Schedule of Regulatory Assets and Liabilities [Line Items]

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

223

182

Schedule of Regulatory Assets and Liabilities [Line Items]

Houston Electric [Member] | Amounts related to TCJA [Member]

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

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

^[2],[5]

Schedule of Regulatory Assets and Liabilities [Line Items]

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

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

Remaining amounts of regulatory assets for which no return on investment during recovery period is provided

^[6]

^[2]

Houston Electric [Member] | Hurricane Harvey [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

Securitized regulatory assets

Unrecognized equity return (2)

^[1]

Unamortized loss on reacquired debt (3)

^[2]

191

181

Total regulatory assets

203

258

Total regulatory liabilities

1,219

1,227

1,266

1,248

Total regulatory assets and liabilities, net

(1,063)

(990)

CERC Corp [Member] | Prepaid Expenses and Other Current Assets [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory assets (1)

^[3]

CERC Corp [Member] | Other Current Liabilities [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Current regulatory liabilities (6)

^[4]

CERC Corp [Member] | Amounts related to TCJA [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

CERC Corp [Member] | Removal Costs [Member]

^[5]

442

476

Schedule of Regulatory Assets and Liabilities [Line Items]

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

637

617

Schedule of Regulatory Assets and Liabilities [Line Items]

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

140

134

Schedule of Regulatory Assets and Liabilities [Line Items]

CERC Corp [Member] | Amounts related to TCJA [Member]

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

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

^[2],[5]

Schedule of Regulatory Assets and Liabilities [Line Items]

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

^[2]

Schedule of Regulatory Assets and Liabilities [Line Items]

Remaining amounts of regulatory assets for which no return on investment during recovery period is provided

^[6]

^[2]

CERC Corp [Member] | Hurricane Harvey [Member]

Schedule of Regulatory Assets and Liabilities [Line Items]

Schedule of Short-term Borrowings and Long-term Debt [Table Text Block]

^[2]

$ 4

[1]

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.



	Year Ended December 31,
	2019				2018				2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric

Allowed equity return recognized	$	45	$	45	$	74	$	74	$	42	$	42

[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 Consolidated Balance Sheets.

[4]

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

[5]

The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities. See Note 15 for additional information.

[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.

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
ZENS-Related Securities
ZENS-Related Securities	$ 540,000,000
Proceeds from sale and maturity of marketable securities	0	$ (398,000,000)	$ 0
Gain (loss) on ZENS-Related Securities	282,000,000	(22,000,000)	7,000,000
ZENS-Related Securities	822,000,000	540,000,000
Debt component of ZENS
Debt Component of ZENS	24,000,000
Distribution to ZENS holders	0	(398,000,000)	0
Debt Component of ZENS	19,000,000	24,000,000
Derivative component of ZENS
Derivative Component of ZENS	601,000,000
Distribution to ZENS holders	0	(398,000,000)	0
Loss (gain) on indexed debt securities	292,000,000	232,000,000	(49,000,000)
Derivative Component of ZENS	$ 893,000,000	$ 601,000,000
AT&T Common [Member]
Indexed Debt Securities [Line Items]
Balance of investment owned (in shares)	10,212,945	10,212,945
Charter Common [Member]
Indexed Debt Securities [Line Items]
Balance of investment owned (in shares)	872,503	872,912
ZENS-Related Securities [Member]
ZENS-Related Securities
ZENS-Related Securities	$ 540,000,000	$ 960,000,000	953,000,000
Proceeds from sale and maturity of marketable securities		(398,000,000)
Gain (loss) on ZENS-Related Securities	282,000,000	(22,000,000)	7,000,000
ZENS-Related Securities	822,000,000	540,000,000	960,000,000
Debt Component Of ZENS [Member]
Debt component of ZENS
Debt Component of ZENS	24,000,000	122,000,000	114,000,000
Accretion of debt component of ZENS	17,000,000	21,000,000	27,000,000
2 % interest paid	(17,000,000)	(17,000,000)	(17,000,000)
Distribution to ZENS holders	(5,000,000)	(102,000,000)	(2,000,000)
Debt Component of ZENS	19,000,000	24,000,000	122,000,000
Derivative component of ZENS
Distribution to ZENS holders	(5,000,000)	(102,000,000)	(2,000,000)
Derivative Component Of ZENS [Member]
Debt component of ZENS
Distribution to ZENS holders	0	(46,000,000)	0
Derivative component of ZENS
Derivative Component of ZENS	601,000,000	668,000,000	717,000,000
Distribution to ZENS holders	0	(46,000,000)	0
Loss (gain) on indexed debt securities	292,000,000	(21,000,000)	(49,000,000)
Derivative Component of ZENS	893,000,000	$ 601,000,000	$ 668,000,000
Subordinated Debt ZENS Member
Indexed Debt Securities [Line Items]
Principal amount of debt issued	1,000,000,000.0
Outstanding debt balance	$ 828,000,000
Subordinated note cash exchangeable percentage of fair value	95.00%
ZENS annual interest rate	2.00%
Target annual yield on referenced shares before increase or decrease of principal amount of subordinated note	2.309%
Contingent principal amount of indexed debt securities issued by CenterPoint Energy in September 1999 and outstanding and exchangeable	$ 75,000,000
The cash exchange amount from referenced shares per $1,000 face amount of individual notes	944
Face amount of each indexed debt security notes issued by CenterPoint Energy in September 1999	$ 1,000
Subordinated Debt ZENS Member \| AT&T Common [Member]
Indexed Debt Securities [Line Items]
Number of shares referenced in exchangeable subordinated note	0.7185	0.7185
Subordinated Debt ZENS Member \| Charter Common [Member]
Indexed Debt Securities [Line Items]
Number of shares referenced in exchangeable subordinated note	0.061382	0.061382

Short Term Borrowings and Long Term Debt (Tables)

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
CenterPoint Energy:
ZENS due 2029 (2)	$	—		$	19	$	—		$	24
Senior notes 2.50% to 7.08% due 2020 to 2049 (3)	3,728			100		2,000			—
Variable rate term loans 2.275% to 2.56% due 2020 to 2021	1,000			500		—			—
First mortgage bonds 2.19% to 6.72% due 2022 to 2055 (4)	293			—		—			—
Pollution control bonds 5.125% due 2028 (5)	68			—		68			—
Commercial paper (6) (7)	1,901			—		—			—
Unamortized debt issuance costs	(22		)	—		(13		)	—
Unamortized discount and premium, net	(7		)	—		(2		)	—
Houston Electric debt (see details below)	4,719			231		4,258			458
CERC debt (see details below)	2,546			—		2,371			—
Other debt	18			18		—			—
Total CenterPoint Energy debt	$	14,244		$	868	$	8,682		$	482



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
Houston Electric:
First mortgage bonds 9.15% due 2021	$	102		$	—	$	102		$	—
General mortgage bonds 1.85% to 6.95% due 2021 to 2049	3,912			—		3,212			—
Restoration Bond Company:
System restoration bonds 4.243% due 2022	134			62		197			59
Bond Company II:
Transition bonds 5.302% due 2019	—			—		—			208
Bond Company III:
Transition bonds 5.234% due 2020	—			29		29			56
Bond Company IV:
Transition bonds 2.161% to 3.028% due 2020 to 2024	613			140		753			135
Unamortized debt issuance costs	(27		)	—		(24		)	—
Unamortized discount and premium, net	(15		)	—		(11		)	—
Total Houston Electric debt	$	4,719		$	231	$	4,258		$	458



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
CERC (8):
Senior notes 3.55% to 6.625% due 2021 to 2047	$	2,193		$	—	$	2,193		$	—
Commercial paper (6)	377			—		210			—
Unamortized debt issuance costs	(13		)	—		(15		)	—
Unamortized discount and premium, net	(11		)	—		(17		)	—
Total CERC debt	$	2,546		$	—	$	2,371		$	—


(1)	Includes amounts due or exchangeable within one year of the date noted.


(2)	CenterPoint Energy’s ZENS obligation is bifurcated into a debt component and an embedded derivative component. For additional information regarding ZENS, see Note 12(b). As ZENS are exchangeable for cash at any time at the option of the holders, these notes are classified as a current portion of long-term debt.

(3)

Includes $532 million of senior notes issued by VUHI and $96 million of senior notes issued by Indiana Gas. The senior notes have stated interest rates that range from 3.72% to 7.08%. The senior notes issued by VUHI are guaranteed by SIGECO, Indiana Gas and VEDO. 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 of senior notes 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.


(4)	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture.


(5)	$68 million and $68 million of these series of debt were secured by general mortgage bonds of Houston Electric as of December 31, 2019 and 2018, respectively. These general mortgage bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.


(6)	Classified as long-term debt because the termination date of the facility that backstops the commercial paper is more than one year from the date noted.


(7)	Commercial paper issued by VUHI has maturities up to 30 days.


(8)	Issued by CERC Corp.

Long-term Debt

Debt Retirements. During the year ended December 31, 2019, CenterPoint Energy retired the following debt instruments:

Retirement Date

Debt Instrument

Aggregate Principal Amount

Interest Rate

Maturity Date

(in millions)

CenterPoint Energy

December 2019

Guaranteed senior notes

3.33%

2022

CenterPoint Energy

December 2019

Guaranteed senior notes

4.53%

2025

In December 2019, VCC redeemed the aggregate principal amount of its guaranteed senior notes at a redemption price equal to 100% of the principal amount thereof, plus accrued and unpaid interest thereon to but excluding the redemption date, plus the make-whole premium. The make-whole premium associated with the two redemptions was approximately $1 million and was included in Other Income, net on CenterPoint Energy’s Statements of Consolidated Income.

Debt Transactions. During the year ended December 31, 2019, the following debt instruments were issued or incurred:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of December 31, 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		2.275%	2020
CenterPoint Energy	May 2019	Variable rate term loan	1,000		2.56%	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.

Schedule of Revolving Credit Facilities and Utilization of Such Facilities [Table Text Block]

The Registrants had the following revolving credit facilities as of December 31, 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 December 31, 2019 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	3,300	1.500%	65%	(3)	59.0%	March 3, 2022
July 14, 2017	CenterPoint Energy (4)	400		1.125%	65%		51.6%	July 14, 2022
July 14, 2017	CenterPoint Energy (5)	200		1.250%	65%		58.0%	July 14, 2022
March 3, 2016	Houston Electric	300		1.125%	65%	(3)	50.2%	March 3, 2022
March 3, 2016	CERC	900		1.250%	65%		46.4%	March 3, 2022
	Total	$	5,100


(1)	Based on credit ratings as of December 31, 2019.


(2)	As defined in the revolving credit facility agreement, 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, as well as the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of December 31, 2019.

As of December 31, 2019 and 2018, the Registrants had the following revolving credit facilities and utilization of such facilities:



	December 31, 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	$	1,633	1.95	%	$	—	$	6	$	—	—	%
CenterPoint Energy (2)	—		—		268		2.08	%	—		—		—		—	%
CenterPoint Energy (3)	—		—		—		—	%	—		—		—		—	%
Houston Electric	—		—		—		—	%	—		4		—		—	%
CERC	—		1		377		1.94	%	—		1		210		2.93	%
Total	$	—	$	7	$	2,278			$	—	$	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.

In January 2019, CenterPoint Energy issued the following commercial paper in connection with the closing of the Merger:



Registrant	Issuance Date	Debt Instrument	Aggregate Principal Amount		Weighted Average Interest Rate
			(in millions)
CenterPoint Energy (1) (2)	January 2019	Commercial paper	$	1,660	2.88%


(1)	Proceeds from these commercial paper issuances were used to fund a portion of the Merger and to pay related fees and expenses and were contributed to Vectren for its payment of its stub period cash dividend, long-term incentive payments and to fund the repayment of indebtedness of Vectren subsidiaries redeemed at the option of the holder as a result of the closing of the Merger.

(2)

The commercial paper notes were issued at various times in January 2019 with maturities up to and including 90 days as of the time of issuance, and, prior to their use as described in connection with the closing of the Merger, the net proceeds of such issuances were invested in short-term investments.

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

Maturities. As of December 31, 2019, maturities of long-term debt, capital leases and sinking fund requirements, excluding the ZENS obligation, are as follows:



	CenterPoint Energy (1)		Houston Electric (1)		CERC		Securitization Bonds
	(in millions)
2020	$	831	$	231	$	—	$	231
2021	2,761		613		593		211
2022	3,302		519		376		219
2023	713		356		300		156
2024	1,184		162		—		162

(1)

These maturities include Securitization Bonds principal repayments on scheduled payment dates.

Revenue Recognition

12 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue Recognition [Text Block]

Revenue Recognition

The Registrants adopted ASC 606, Revenue from Contracts with Customers, and all related amendments on January 1, 2018 using the modified retrospective method for those contracts that were not completed as of the date of adoption. Application of the new revenue standard did not result in a cumulative effect adjustment to the opening balance of retained earnings. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The adoption of the new standard did not have a material impact on the Registrants’ financial position, results of operations or cash flows.

In accordance with ASC 606, 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



	Year Ended December 31, 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	$	2,984		$	523	$	3,680		$	479		$	1,190		$	295	$	9,151
Derivatives income	6			—		2			3,303			—			—		3,311
Other (3)	6			—		1			—			—			5		12
Eliminations	—			—		(40		)	(129		)	(4		)	—		(173		)
Total revenues	$	2,996		$	523	$	3,643		$	3,653		$	1,186		$	300	$	12,301

	Year Ended December 31, 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	$	3,235		$	—	$	3,011		$	493		$	—		$	6	$	6,745
Derivatives income	(2		)	—		(2		)	4,028			—			—		4,024
Other (3)	(1		)	—		(42		)	—			—			9		(34		)
Eliminations	—			—		(36		)	(110		)	—			—		(146		)
Total revenues	$	3,232		$	—	$	2,931		$	4,411		$	—		$	15	$	10,589

	Year Ended December 31, 2017
	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	$	3,001		$	—	$	2,638		$	480		$	—		$	5	$	6,124
Derivatives income	(1		)	—		—			3,569			—			—		3,568
Other (3)	(3		)	—		1			—			—			9		7
Eliminations	—			—		(33		)	(52		)	—			—		(85		)
Total revenues	$	2,997		$	—	$	2,606		$	3,997		$	—		$	14	$	9,614


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


(2)	Reflected in Non-utility revenues in the 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 December 31, 2019.

Houston Electric



	Year Ended December 31,
	2019		2018			2017
	(in millions)
Revenue from contracts	$	2,984	$	3,235		$	3,001
Other (1)	6		(1		)	(3		)
Total revenues	$	2,990	$	3,234		$	2,998

(1)

CERC



	Year Ended December 31, 2019
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,945		$	480		$	5	$	3,430
Derivatives income	2			3,302			—		3,304
Other (3)	4			—			—		4
Eliminations	(40		)	(128		)	—		(168		)
Total revenues	$	2,911		$	3,654		$	5	$	6,570

	Year Ended December 31, 2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	3,011		$	493		$	1	$	3,505
Derivatives income	(2		)	4,028			—		4,026
Other (3)	(42		)	—			—		(42		)
Eliminations	(36		)	(110		)	—		(146		)
Total revenues	$	2,931		$	4,411		$	1	$	7,343

	Year Ended December 31, 2017
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,638		$	480		$	—	$	3,118
Derivatives income	—			3,569			—		3,569
Other (3)	1			—			—		1
Eliminations	(33		)	(52		)	—		(85		)
Total revenues	$	2,606		$	3,997		$	—	$	6,603


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


(2)	Reflected in Non-utility revenues in the 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 the PUCT, 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 the PUCT. Payments for electricity distribution and discretionary services are aggregated and received on a monthly basis. Houston Electric performs transmission services over time as a stand-ready obligation to provide a reliable network of transmission systems. Revenue is recognized upon time elapsed, and the monthly tariff rate set by the PUCT. 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). CERC distributes and transports natural gas to customers over time, and customers consume the natural gas when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by the state governing agency for that service area, is recognized as natural gas is delivered and represents amounts both billed and unbilled. Discretionary services requested by the customer are satisfied at a point in time and revenue is recognized upon completion of service and the tariff rates set by the applicable state regulator. Payments of natural gas distribution, transportation and discretionary services are aggregated and received on a monthly basis.

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.

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

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 Consolidated Balance Sheets. On an aggregate basis as of December 31, 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 Consolidated Balance Sheets. On an aggregate basis as of December 31, 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 year ended December 31, 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)	$	516	$	373	$	—	$	3
Closing balance as of December 31, 2019	800		579		61		34
Increase	$	284	$	206	$	61	$	31


(1)	Opening balances related to Vectren are as of February 1, 2019, and are thus excluded from the opening balance as of December 31, 2018.

The amount of revenue recognized in the year ended December 31, 2019 that was included in the opening contract liability was $47 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, plus the addition of obligations acquired in the Merger.

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 December 31, 2019	210			117		3
Increase (decrease)	$	(24	)	$	7	$	—

The amount of revenue recognized in the year ended December 31, 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 December 31, 2019	282		250
Increase (decrease)	$	—	$	(13	)

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 and energy performance and sustainable infrastructure services contracts of ESG, which are included in Corporate and Other.



	Rolling 12 Months		Thereafter		Total
	(in millions)
Revenue expected to be recognized on contracts in place as of December 31, 2019:
Infrastructure Services	$	254	$	—	$	254
Corporate and Other	84		752		836
	$	338	$	752	$	1,090

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.

Commitments and Contingencies (Details)	12 Months Ended
Commitments and Contingencies (Details)	Dec. 31, 2019 USD ($) site	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Purchase Obligations
2020	$ 750,000,000
2021	617,000,000
2022	418,000,000
2023	335,000,000
2024	271,000,000
2025 and beyond	$ 1,888,000,000
Performance Guarantees & Product Warranties [Abstract]
Number of surety bond obligations outstanding	62
Performance guarantee obligations outstanding face amount	$ 565,000,000
Percentage of work yet to be completed on projects with open surety bonds	36.00%
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 499,000,000
Legal, Environmental and Other Matters
Asset Retirement Obligation	$ 539,000,000	$ 258,000,000	$ 281,000,000
Indiana Gas Service Territory [Member]
Legal, Environmental and Other Matters
Environmental remediation number of sites with potential remedial responsibility \| site	26
Minnesota and Indiana Gas Service Territories [Member]
Legal, Environmental and Other Matters
Liability recorded for remediation of Minnesota sites	$ 12,000,000
Minnesota and Indiana Gas Service Territories [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 7,000,000
Years to resolve contingency	5
Minnesota and Indiana Gas Service Territories [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 51,000,000
Years to resolve contingency	50
Minnehaha Academy Gas Explosion [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000
Indiana Electric [Member]
Legal, Environmental and Other Matters
Asset Retirement Obligation	68,000,000
Indiana Electric [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated capital expenditure to clean ash ponds	60,000,000
Indiana Electric [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated capital expenditure to clean ash ponds	80,000,000
CERC Corp [Member]
Purchase Obligations
2020	533,000,000
2021	432,000,000
2022	242,000,000
2023	182,000,000
2024	174,000,000
2025 and beyond	1,526,000,000
Legal, Environmental and Other Matters
Asset Retirement Obligation	325,000,000	$ 221,000,000	$ 243,000,000
CERC Corp [Member] \| Minnesota and Indiana Gas Service Territories [Member]
Legal, Environmental and Other Matters
Liability recorded for remediation of Minnesota sites	7,000,000
CERC Corp [Member] \| Minnesota and Indiana Gas Service Territories [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 4,000,000
Years to resolve contingency	30
CERC Corp [Member] \| Minnesota and Indiana Gas Service Territories [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 32,000,000
Years to resolve contingency	50
CERC Corp [Member] \| Minnehaha Academy Gas Explosion [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000
CES natural gas related transactions [Member] \| Energy Services [Member]
Performance Guarantees & Product Warranties [Abstract]
Performance guarantee obligations outstanding face amount	1,800,000,000
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 0
Annualized fee received for retained CES obligation guarantees	3.00%
Quarterly increase of fee received for retained CES guarantee exposure	1.00%
Guarantor Obligations, Current Carrying Value	$ 0
CES natural gas related transactions [Member] \| Energy Services [Member] \| CERC Corp [Member]
Performance Guarantees & Product Warranties [Abstract]
Performance guarantee obligations outstanding face amount	$ 1,800,000,000
Annualized fee received for retained CES obligation guarantees	3.00%
Quarterly increase of fee received for retained CES guarantee exposure	1.00%
Guarantor Obligations, Current Carrying Value	$ 0

Supplemental Disclosure of Cash Flow Information (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Interest, net of capitalized interest

$ 436

$ 363

$ 378

Income taxes (refunds), net

155

Accounts payable related to capital expenditures

236

201

144

Capital distribution associated with the Internal Spin

ROU Asset Obtained In Exchange for Operating Lease Liability, Including Transition Impact of ASC 842 Adoption

^[1]

Total cash, cash equivalents and restricted cash shown in Statements of Consolidated Cash Flows

^[2]

241

4,231

271

4,278

296

$ 381

Other, net [Member]

Interest income

Cash and Cash Equivalents [Member]

Temporary investments

3,900

Prepaid Expenses and Other Current Assets [Member]

Other Noncurrent Assets [Member]

Interest, net of capitalized interest

229

200

205

Income taxes (refunds), net

154

Accounts payable related to capital expenditures

117

124

104

Capital distribution associated with the Internal Spin

ROU Asset Obtained In Exchange for Operating Lease Liability, Including Transition Impact of ASC 842 Adoption

^[1]

Total cash, cash equivalents and restricted cash shown in Statements of Consolidated Cash Flows

^[3]

216

335

235

370

274

381

Houston Electric [Member] | Other, net [Member]

Interest Income, Other

Houston Electric [Member] | Prepaid Expenses and Other Current Assets [Member]

Houston Electric [Member] | Other Noncurrent Assets [Member]

Interest, net of capitalized interest

109

105

116

Income taxes (refunds), net

Accounts payable related to capital expenditures

Capital distribution associated with the Internal Spin

^[4],[5]

1,473

^[5]

ROU Asset Obtained In Exchange for Operating Lease Liability, Including Transition Impact of ASC 842 Adoption

^[1]

Total cash, cash equivalents and restricted cash shown in Statements of Consolidated Cash Flows

$ 12

$ 1

CERC Corp [Member] | Prepaid Expenses and Other Current Assets [Member]

CERC Corp [Member] | Other Noncurrent Assets [Member]

Bond Companies [Member] | Houston Electric [Member]

$ 216

$ 335

[1]	Includes the transition impact of adoption of ASU 2016-02 Leases as of January 1, 2019. The Registrants elected not to recast comparative periods in the year of adoption as permitted by the standard.
[2]	CenterPoint Energy’s Cash and cash equivalents as of December 31, 2018 included $3.9 billion of temporary investments resulting from the Merger financings. CenterPoint Energy recorded interest income of $22 million, $28 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on CenterPoint Energy’s Statements of Consolidated Income. See Notes 13 and 14 for further details related to the Merger financings.
[3]	Houston Electric’s Cash and cash equivalents as of December 31, 2019 and 2018 included $216 million and $335 million, respectively, of cash related to the Bond Companies. Houston Electric recorded interest income of $9 million, $4 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on Houston Electric’s Statement of Consolidated Income.
[4]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.
[5]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.

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

1 Months Ended

12 Months Ended

Dec. 30, 2019

USD ($)

Jan. 31, 2019

USD ($)

Dec. 31, 2019

USD ($)

day

Aug. 12, 2019

USD ($)

May 15, 2019

USD ($)

Feb. 08, 2019

USD ($)

^[1]

Jan. 15, 2019

USD ($)

Dec. 31, 2018

USD ($)

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 5,100,000,000

Number of days until commercial paper maturity | day

Senior Notes due 2022 [Member]

Amount of debt retired

$ 3,000,000

Senior Notes due 2025 [Member]

3.33%

Amount of debt retired

$ 6,000,000

Variable rate term loan [Member]

4.53%

2.275%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 1,000,000,000

$ 25,000,000

Variable term rate loan 2 [Member]

$ 1,000,000,000

Senior Notes Due 2030 [Member]

2.56%

Senior Notes Due 2049 [Member]

2.95%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

3.70%

Commercial paper (4)

Pollution control bonds 5.125% due 2028 (5)

^[2]

$ 1,901,000,000

^[3]

$ 0

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Senior Notes due 2022 and 2025 [Member]

^[4]

68,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Make-whole premium

$ 1,000,000

Securitization Bonds [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

231,000,000

211,000,000

219,000,000

156,000,000

162,000,000

Long term Debt Excluding ZENS [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

2020

^[5]

831,000,000

2021

^[5]

2,761,000,000

2022

^[5]

3,302,000,000

2023

^[5]

713,000,000

2024

^[5]

1,184,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

300,000,000

2020

^[5]

231,000,000

2021

^[5]

613,000,000

2022

^[5]

519,000,000

2023

^[5]

356,000,000

2024

^[5]

162,000,000

Additional first mortgage bonds and general mortgage bonds that could be issued

$ 3,700,000,000

Percentage of property additions

70.00%

Houston Electric [Member] | General Mortgage Bonds Due 2049 [Member]

4.25%

Houston Electric [Member] | First mortgage bonds 9.15% due 2021

$ 700,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

9.15%

Secured debt amount with asset liens

$ 102,000,000

Replacement fund requirements to be satisfied in 2018

295,000,000

Sinking fund requirements to be satisfied in 2018

1,600,000

Houston Electric [Member] | General mortgage bonds 1.85% to 6.95% due 2021 to 2048

102,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Secured debt amount with asset liens

4,000,000,000.0

3,912,000,000

3,212,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

900,000,000

593,000,000

376,000,000

300,000,000

CERC Corp [Member] | Commercial paper (4)

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Revolving Credit Facility [Member]

^[2],[6]

377,000,000

210,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Revolving Credit Facility [Member] | Houston Electric [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Revolving Credit Facility [Member] | CERC Corp [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Line of Credit [Member] | Houston Electric [Member]

$ 0

Percentage on limitation of debt to total capitalization under covenant (in hundredths)

^[7]

65.00%

Line of Credit [Member] | CERC Corp [Member]

^[8]

0.502

Percentage on limitation of debt to total capitalization under covenant (in hundredths)

65.00%

Line of Credit [Member] | London Interbank Offered Rate (LIBOR) [Member] | Houston Electric [Member]

^[8]

0.464

Line of Credit [Member] | London Interbank Offered Rate (LIBOR) [Member] | CERC Corp [Member]

^[9]

1.125%

Letter of Credit [Member]

^[9]

1.25%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Letter of Credit [Member] | Houston Electric [Member]

$ 7,000,000

11,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Letter of Credit [Member] | CERC Corp [Member]

4,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

1,000,000

Commercial paper (4)

Commercial paper (4) | Houston Electric [Member]

2,278,000,000

210,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 0

Commercial paper (4) | CERC Corp [Member]

0.00%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 377,000,000

$ 210,000,000

1.94%

2.93%

Vectren [Member] | Commercial paper (4)

Long-term line of credit

Weighted average interest rate of commercial paper issued in connection with the Merger

^[10],[11]

2.88%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

SIGECO [Member] | Letter of Credit [Member]

^[10],[11]

$ 1,660,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 21,000,000

Parent Company [Member]

Parent Company [Member] | Senior Notes Due 2030 [Member]

$ 3,300,000,000

Parent Company [Member] | Senior Notes Due 2024 [Member]

$ 400,000,000

2.50%

Parent Company [Member] | Senior Notes Due 2049 [Member]

500,000,000

Parent Company [Member] | Pollution control bonds 5.125% due 2028 (5)

$ 300,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

5.125%

Secured debt amount with asset liens

$ 68,000,000

Parent Company [Member] | Revolving Credit Facility [Member]

68,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Parent Company [Member] | Line of Credit [Member]

^[12]

$ 0

Percentage on limitation of debt to total capitalization under covenant (in hundredths)

^[7]

65.00%

Percentage on limitation of debt to total capitalization under covenant amended (in hundredths)

^[8]

0.590

70.00%

System restoration costs threshold for increase in permitted debt to EBITDA covenant ratio

$ 100,000,000

Consecutive period for system restoration costs to exceed $100 million (in months)

Parent Company [Member] | Line of Credit [Member] | London Interbank Offered Rate (LIBOR) [Member]

Parent Company [Member] | Letter of Credit [Member]

^[9]

1.50%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Parent Company [Member] | Commercial paper (4)

^[12]

$ 6,000,000

6,000,000

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

^[12]

$ 1,633,000,000

$ 0

^[12]

1.95%

0.00%

VUHI [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

^[13]

$ 400,000,000

Credit facility swing line sublimit

10,000,000

Letters of credit swing line sublimit

20,000,000

VUHI [Member] | Revolving Credit Facility [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

VUHI [Member] | Line of Credit [Member]

$ 0

^[14]

$ 0

Percentage on limitation of debt to total capitalization under covenant (in hundredths)

^[13]

65.00%

VUHI [Member] | Line of Credit [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[8],[13]

0.516

VUHI [Member] | Letter of Credit [Member]

^[9],[13]

1.125%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

VUHI [Member] | Commercial paper (4)

$ 0

^[14]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 268,000,000

^[14]

$ 0

2.08%

^[14]

0.00%

VCC [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

^[15]

$ 200,000,000

Credit facility swing line sublimit

40,000,000

Letters of credit swing line sublimit

80,000,000

VCC [Member] | Revolving Credit Facility [Member]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

VCC [Member] | Line of Credit [Member]

$ 0

^[16]

$ 0

Percentage on limitation of debt to total capitalization under covenant (in hundredths)

^[15]

65.00%

VCC [Member] | Line of Credit [Member] | London Interbank Offered Rate (LIBOR) [Member]

^[8],[15]

0.580

VCC [Member] | Letter of Credit [Member]

^[9],[15]

1.25%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

VCC [Member] | Commercial paper (4)

$ 0

^[16]

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

$ 0

^[16]

$ 0

Maximum [Member] | Houston Electric [Member] | General mortgage bonds 1.85% to 6.95% due 2021 to 2048

0.00%

^[16]

0.00%

Maximum [Member] | Parent Company [Member] | Variable rate term loan [Member]

6.95%

Maximum [Member] | Vectren [Member] | Letter of Credit [Member]

2.56%

Annual maturities of long term debt, capital leases, and sinking fund requirements, excluding ZENS obligations [Abstract]

Quarterly Financial Information Disclosure [Abstract]

$ 50,000,000

[1]	Draw down by VCC on its variable rate term loan.
[2]	Classified as long-term debt because the termination date of the facility that backstops the commercial paper is more than one year from the date noted.
[3]	Commercial paper issued by VUHI has maturities up to 30 days.
[4]	$68 million and $68 million of these series of debt were secured by general mortgage bonds of Houston Electric as of December 31, 2019 and 2018, respectively. These general mortgage bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.
[5]	These maturities include Securitization Bonds principal repayments on scheduled payment dates.
[6]	Issued by CERC Corp.
[7]	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.
[8]	As defined in the revolving credit facility agreement, excluding Securitization Bonds.
[9]	Based on credit ratings as of December 31, 2019.
[10]	Proceeds from these commercial paper issuances were used to fund a portion of the Merger and to pay related fees and expenses and were contributed to Vectren for its payment of its stub period cash dividend, long-term incentive payments and to fund the repayment of indebtedness of Vectren subsidiaries redeemed at the option of the holder as a result of the closing of the Merger.
[11]	The commercial paper notes were issued at various times in January 2019 with maturities up to and including 90 days as of the time of issuance, and, prior to their use as described in connection with the closing of the Merger, the net proceeds of such issuances were invested in short-term investments.
[12]	CenterPoint Energy’s outstanding commercial paper generally has maturities of 60 days or less.
[13]	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.
[14]	This credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.
[15]	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.
[16]	This credit facility was issued by VCC and is guaranteed by Vectren.

Unaudited Quarterly Information (Tables)

12 Months Ended

Dec. 31, 2019

Quarterly Financial Data [Table Text Block]

Summarized quarterly financial data is as follows:



	Year Ended December 31, 2019
	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
	(in millions, except per share amounts)
CenterPoint Energy
Revenues	$	3,531	$	2,798	$	2,742		$	3,230
Operating income	245		287		392			302
Income available to common shareholders	140		165		241			128
Basic earnings per common share (1)	0.28		0.33		0.48			0.25
Diluted earnings per common share (1)	0.28		0.33		0.47			0.25
Houston Electric
Revenues	686		765		859			680
Operating income	81		169		269			99
Net income	27		100		185			44
CERC
Revenues	2,368		1,342		1,126			1,734
Operating income	196		58		23			73
Net income (loss)	138		28		(7		)	53



	Year Ended December 31, 2018
	First Quarter		Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per share amounts)
CenterPoint Energy
Revenues	$	3,155	$	2,186		$	2,212		$	3,036
Operating income	251		187			226			167
Income (loss) available to common shareholders	165		(75		)	153			90
Basic earnings (loss) per common share (1)	0.38		(0.17		)	0.35			0.18
Diluted earnings (loss) per common share (1)	0.38		(0.17		)	0.35			0.18
Houston Electric
Revenues	755		854			897			728
Operating income	119		181			227			98
Net income	52		101			143			40
CERC (2)
Revenues	2,400		1,328			1,312			2,303
Operating income (loss)	131		22			(7		)	76
Income (loss) from continuing operations	78		(8		)	(35		)	35
Income (loss) from discontinued operations	52		44			44			(2		)
Net income	130		36			9			33


(1)	Quarterly earnings (loss) per common share are based on the weighted average number of shares outstanding during the quarter, and the sum of the quarters may not equal annual earnings (loss) per common share.


(2)	Amounts have been recast to reflect discontinued operations in all periods presented.

Stock-Based Incentive Compensation Plans and Employee Benefit Plans Stock Based Incentive Compensation (Details) - USD ($)
$ / shares in Units, shares in Thousands, $ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Shares authorized for issuance under long-term incentive plans (in shares)

14,000

Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]

Income tax benefit recognized related to LTIPs

$ 7

$ 6

$ 8

Actual tax benefit realized for tax deductions

$ 12

$ 5

$ 6

Performance Awards [Member]

Summary of nonvested shares [Roll Forward]

Nonvested, beginning of period (in shares)

^[1]

3,818

Granted (in shares)

^[1]

1,413

Forfeited or cancelled (in shares)

^[1]

(825)

Vested and released to participants (in shares)

^[1]

(1,074)

Nonvested, end of period (in shares)

^[1]

3,332

3,818

Weighted average grant date fair value, nonvested, beginning of period (in dollars per share)

^[1]

$ 23.91

Weighted average grant date fair values of awards granted (in dollars per share)

31.16

^[1]

$ 26.74

$ 26.64

Weighted average grant date fair value, forfeited or cancelled (in dollars per share)

^[1]

24.78

Weighted average grant date fair value, vested and released to participants (in dollars per share)

^[1]

18.97

Weighted average grant date fair value, nonvested, end of period (in dollars per share)

^[1]

$ 28.36

$ 23.91

Remaining average contractual life of nonvested shares outstanding (in years)

1 year 1 month 6 days

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested

^[1],[2]

$ 53

Total intrinsic value of awards received by participants

$ 12

$ 7

Total grant date fair values of performance and stock awards which vested during the period

$ 20

$ 9

$ 5

Stock Awards [Member]

Summary of nonvested shares [Roll Forward]

Nonvested, beginning of period (in shares)

1,060

Granted (in shares)

470

Forfeited or cancelled (in shares)

(131)

Vested and released to participants (in shares)

(433)

Nonvested, end of period (in shares)

966

1,060

Weighted average grant date fair value, nonvested, beginning of period (in dollars per share)

$ 24.08

Weighted average grant date fair values of awards granted (in dollars per share)

31.07

$ 26.62

$ 26.77

Weighted average grant date fair value, forfeited or cancelled (in dollars per share)

27.95

Weighted average grant date fair value, vested and released to participants (in dollars per share)

20.72

Weighted average grant date fair value, nonvested, end of period (in dollars per share)

$ 28.46

$ 24.08

Remaining average contractual life of nonvested shares outstanding (in years)

1 year 2 months 12 days

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested

^[2]

$ 26

Total intrinsic value of awards received by participants

$ 9

Total grant date fair values of performance and stock awards which vested during the period

Performance and Stock Awards [Member]

Summary of nonvested shares [Roll Forward]

Unrecognized compensation cost related to non-vested performance and stock awards

$ 34

Weighted average period of recognition (in years)

1 year 8 months 12 days

Operation And Maintenance Expense [Member]

Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]

LTIP compensation expense

^[3]

$ 28

$ 26

$ 21

[1]	Reflects maximum performance achievement.
[2]	Reflects the impact of current expectations of achievement and stock price.
[3]	Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income and shown prior to any amounts capitalized.

Short Term Borrowings and Long Term Debt

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

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

Short-term Borrowings and Long-term Debt



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
CenterPoint Energy:
ZENS due 2029 (2)	$	—		$	19	$	—		$	24
Senior notes 2.50% to 7.08% due 2020 to 2049 (3)	3,728			100		2,000			—
Variable rate term loans 2.275% to 2.56% due 2020 to 2021	1,000			500		—			—
First mortgage bonds 2.19% to 6.72% due 2022 to 2055 (4)	293			—		—			—
Pollution control bonds 5.125% due 2028 (5)	68			—		68			—
Commercial paper (6) (7)	1,901			—		—			—
Unamortized debt issuance costs	(22		)	—		(13		)	—
Unamortized discount and premium, net	(7		)	—		(2		)	—
Houston Electric debt (see details below)	4,719			231		4,258			458
CERC debt (see details below)	2,546			—		2,371			—
Other debt	18			18		—			—
Total CenterPoint Energy debt	$	14,244		$	868	$	8,682		$	482



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
Houston Electric:
First mortgage bonds 9.15% due 2021	$	102		$	—	$	102		$	—
General mortgage bonds 1.85% to 6.95% due 2021 to 2049	3,912			—		3,212			—
Restoration Bond Company:
System restoration bonds 4.243% due 2022	134			62		197			59
Bond Company II:
Transition bonds 5.302% due 2019	—			—		—			208
Bond Company III:
Transition bonds 5.234% due 2020	—			29		29			56
Bond Company IV:
Transition bonds 2.161% to 3.028% due 2020 to 2024	613			140		753			135
Unamortized debt issuance costs	(27		)	—		(24		)	—
Unamortized discount and premium, net	(15		)	—		(11		)	—
Total Houston Electric debt	$	4,719		$	231	$	4,258		$	458



	December 31, 2019					December 31, 2018
	Long-Term			Current (1)		Long-Term			Current (1)
	(in millions)
CERC (8):
Senior notes 3.55% to 6.625% due 2021 to 2047	$	2,193		$	—	$	2,193		$	—
Commercial paper (6)	377			—		210			—
Unamortized debt issuance costs	(13		)	—		(15		)	—
Unamortized discount and premium, net	(11		)	—		(17		)	—
Total CERC debt	$	2,546		$	—	$	2,371		$	—


(1)	Includes amounts due or exchangeable within one year of the date noted.


(2)	CenterPoint Energy’s ZENS obligation is bifurcated into a debt component and an embedded derivative component. For additional information regarding ZENS, see Note 12(b). As ZENS are exchangeable for cash at any time at the option of the holders, these notes are classified as a current portion of long-term debt.

(3)


(4)	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture.


(5)	$68 million and $68 million of these series of debt were secured by general mortgage bonds of Houston Electric as of December 31, 2019 and 2018, respectively. These general mortgage bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.


(6)	Classified as long-term debt because the termination date of the facility that backstops the commercial paper is more than one year from the date noted.


(7)	Commercial paper issued by VUHI has maturities up to 30 days.


(8)	Issued by CERC Corp.

Long-term Debt

Debt Retirements. During the year ended December 31, 2019, CenterPoint Energy retired the following debt instruments:

Retirement Date

Debt Instrument

Aggregate Principal Amount

Interest Rate

Maturity Date

(in millions)

CenterPoint Energy

December 2019

Guaranteed senior notes

3.33%

2022

CenterPoint Energy

December 2019

Guaranteed senior notes

4.53%

2025

Debt Transactions. During the year ended December 31, 2019, the following debt instruments were issued or incurred:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of December 31, 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		2.275%	2020
CenterPoint Energy	May 2019	Variable rate term loan	1,000		2.56%	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.

Securitization Bonds. As of December 31, 2019, CenterPoint Energy and Houston Electric had special purpose subsidiaries consisting of the Bond Companies, which they consolidate. The consolidated special purpose subsidiaries are wholly-owned, bankruptcy remote entities that were formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of transition bonds or system restoration bonds and activities incidental thereto. These Securitization Bonds are payable only through the imposition and collection of “transition” or “system restoration” charges, as defined in the Texas Public Utility Regulatory Act, which are irrevocable, non-bypassable charges to provide recovery of authorized qualified costs. CenterPoint Energy and Houston Electric have no payment obligations in respect of the Securitization Bonds other than to remit the applicable transition or system restoration charges they collect as set forth in servicing agreements among Houston Electric, the Bond Companies and other parties. Each special purpose entity is the sole owner of the right to impose, collect and receive the applicable transition or system restoration charges securing the bonds issued by that entity. Creditors of CenterPoint Energy or Houston Electric have no recourse to any assets or revenues of the Bond Companies (including the transition and system restoration charges), and the holders of Securitization Bonds have no recourse to the assets or revenues of CenterPoint Energy or Houston Electric.

Credit Facilities. The Registrants had the following revolving credit facilities as of December 31, 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 December 31, 2019 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	3,300	1.500%	65%	(3)	59.0%	March 3, 2022
July 14, 2017	CenterPoint Energy (4)	400		1.125%	65%		51.6%	July 14, 2022
July 14, 2017	CenterPoint Energy (5)	200		1.250%	65%		58.0%	July 14, 2022
March 3, 2016	Houston Electric	300		1.125%	65%	(3)	50.2%	March 3, 2022
March 3, 2016	CERC	900		1.250%	65%		46.4%	March 3, 2022
	Total	$	5,100


(1)	Based on credit ratings as of December 31, 2019.


(2)	As defined in the revolving credit facility agreement, 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, as well as the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of December 31, 2019.

As of December 31, 2019 and 2018, the Registrants had the following revolving credit facilities and utilization of such facilities:



	December 31, 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	$	1,633	1.95	%	$	—	$	6	$	—	—	%
CenterPoint Energy (2)	—		—		268		2.08	%	—		—		—		—	%
CenterPoint Energy (3)	—		—		—		—	%	—		—		—		—	%
Houston Electric	—		—		—		—	%	—		4		—		—	%
CERC	—		1		377		1.94	%	—		1		210		2.93	%
Total	$	—	$	7	$	2,278			$	—	$	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.

In January 2019, CenterPoint Energy issued the following commercial paper in connection with the closing of the Merger:



Registrant	Issuance Date	Debt Instrument	Aggregate Principal Amount		Weighted Average Interest Rate
			(in millions)
CenterPoint Energy (1) (2)	January 2019	Commercial paper	$	1,660	2.88%


(1)	Proceeds from these commercial paper issuances were used to fund a portion of the Merger and to pay related fees and expenses and were contributed to Vectren for its payment of its stub period cash dividend, long-term incentive payments and to fund the repayment of indebtedness of Vectren subsidiaries redeemed at the option of the holder as a result of the closing of the Merger.


(2)	The commercial paper notes were issued at various times in January 2019 with maturities up to and including 90 days as of the time of issuance, and, prior to their use as described in connection with the closing of the Merger, the net proceeds of such issuances were invested in short-term investments.

Maturities. As of December 31, 2019, maturities of long-term debt, capital leases and sinking fund requirements, excluding the ZENS obligation, are as follows:



	CenterPoint Energy (1)		Houston Electric (1)		CERC		Securitization Bonds
	(in millions)
2020	$	831	$	231	$	—	$	231
2021	2,761		613		593		211
2022	3,302		519		376		219
2023	713		356		300		156
2024	1,184		162		—		162


(1)	These maturities include Securitization Bonds principal repayments on scheduled payment dates.

Liens. As of December 31, 2019, Houston Electric’s assets were subject to liens securing approximately $102 million of first mortgage bonds. Sinking or improvement fund and replacement fund requirements on the first mortgage bonds may be satisfied by certification of property additions. Sinking fund and replacement fund requirements for 2019, 2018 and 2017 have been satisfied by certification of property additions. The replacement fund requirement to be satisfied in 2020 is approximately $295 million, and the sinking fund requirement to be satisfied in 2020 is approximately $1.6 million. CenterPoint Energy expects Houston Electric to meet these 2020 obligations by certification of property additions.

As of December 31, 2019, Houston Electric’s assets were also subject to liens securing approximately $4.0 billion of general mortgage bonds, including approximately $68 million held in trust to secure pollution control bonds for which CenterPoint Energy is obligated. The lien of the general mortgage indenture is junior to that of the mortgage pursuant to which the first mortgage bonds are issued. Houston Electric may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee. Approximately $3.7 billion of additional first mortgage bonds and general mortgage bonds could be issued on the basis of retired bonds and 70% of property additions as of December 31, 2019. Houston Electric has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions.

Other. As of December 31, 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, 2020. As of December 31, 2019, such financial institutions had issued $21 million of letters of credit on behalf of Vectren and certain of its subsidiaries.

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

Fair Value, Assets Measured on a Recurring Basis [Table Text Block]

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 December 31, 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



	December 31, 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	$	825	$	—	$	—	$	—		$	825	$	542	$	—	$	—	$	—		$	542
Investments, including money market funds (2)	49		—		—		—			49		66		—		—		—			66
Natural gas derivatives (3)(4)	—		250		42		(98		)	194		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	874	$	250	$	42	$	(98	)	$	1,068	$	609	$	173	$	47	$	(82	)	$	747



	December 31, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Liabilities
Indexed debt securities derivative	$	—	$	893	$	—	$	—		$	893	$	—	$	601	$	—	$	—		$	601
Interest rate derivatives	—		10		—		—			10		24		—		—		—			24
Natural gas derivatives (3)(4)	—		217		24		(161		)	80		—		191		17		(101		)	107
Hedged portion of natural gas inventory	13		—		—		—			13		—		—		—		—			—
Total liabilities	$	13	$	1,120	$	24	$	(161	)	$	996	$	24	$	792	$	17	$	(101	)	$	732

Houston Electric



	December 31, 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)	$	32	$	—	$	—	$	—	$	32	$	48	$	—	$	—	$	—	$	48
Total assets	$	32	$	—	$	—	$	—	$	32	$	48	$	—	$	—	$	—	$	48
Liabilities
Interest rate derivatives	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24

CERC



	December 31, 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)	—		250		42		(98		)	194		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	13	$	250	$	42	$	(98	)	$	207	$	14	$	173	$	47	$	(82	)	$	152
Liabilities
Natural gas derivatives (3)(4)	$	—	$	195	$	24	$	(161	)	$	58	$	—	$	191	$	17	$	(101	)	$	107
Hedged portion of natural gas inventory	13		—		—		—			13		—		—		—		—			—
Total liabilities	$	13	$	195	$	24	$	(161	)	$	71	$	—	$	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:



	December 31, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	63	$	63	$	19	$	19


(2)	Amounts are included in Prepaid and Other Current Assets and Other Assets in the 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.

Assets and Liabilities Measured at Fair Value on a Recurring Basis Using Significant Unobservable Inputs [Table Text Block]

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:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	30		$	30		$	(622	)	$	46		$	(704	)	$	13
Total gains	17			17			30			30			96			47
Total settlements	(22		)	(22		)	(39		)	(39		)	(11		)	(11		)
Transfers into Level 3	(1		)	(1		)	5			5			14			14
Transfers out of Level 3 (1)	(6		)	(6		)	656			(12		)	(17		)	(17		)
Ending balance (2)	$	18		$	18		$	30		$	30		$	(622	)	$	46

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:
	$	12		$	12		$	18		$	18		$	87		$	38


(1)	During 2018, CenterPoint Energy transferred its indexed debt securities derivative from Level 3 to Level 2 to reflect changes in the significance of the unobservable inputs used in the valuation.

(2)

CenterPoint Energy and CERC did not have significant Level 3 purchases or sales during any of the years ended December 31, 2019, 2018 or 2017.

Estimated Fair Value of Financial Instruments, Debt Instruments [Table Text Block]

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 and CenterPoint Energy’s ZENS indexed debt securities derivative are stated at fair value and are excluded from the table below. The fair value of each debt instrument is determined by multiplying the principal amount of each debt instrument by a combination of historical trading prices and comparable issue data. These liabilities, which are not measured at fair value in the Registrants’ Consolidated Balance Sheets, but for which the fair value is disclosed, would be classified as Level 2 in the fair value hierarchy.



	December 31, 2019						December 31, 2018
	CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	(in millions)
Carrying amount	$	15,093	$	4,950	$	2,546	$	9,140	$	4,717	$	2,371
Fair value	16,067		5,457		2,803		9,308		4,770		2,488


(1)	Includes Securitization Bond debt.

Goodwill and Other Intangibles (CenterPoint Energy and CERC) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

$ 5,164

$ 867

Goodwill impairment charge recorded from annual impairment test

$ 0

411

106

(90)

(41)

Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)

321

Customer Relationships [Member]

3,928

3,239

286

^[1]

(43)

^[1]

(27)

Covenants Not To Compete [Member]

243

^[1]

(4)

(3)

Trade Names [Member]

^[1]

(5)

^[1]

Construction backlog [Member]

^[1]

^[1],[2]

(23)

^[1],[2]

Operation and maintenance agreements [Member]

^[1],[2]

^[1],[2]

(1)

^[1],[2]

^[1],[2]

Other [Member]

^[1]

(14)

^[1]

(11)

Indiana Electric Integrated [Member]

^[1]

1,121

Goodwill impairment charge recorded from annual impairment test

^[3]

1,121

3,312

746

Goodwill impairment charge recorded from annual impairment test

^[3]

2,566

Goodwill impairment charge recorded from annual impairment test

^[4]

110

Accumulated goodwill impairment charge recorded in 2012

252

Goodwill, Impairment Loss, Net of Tax

220

Goodwill impairment charge recorded from annual impairment test

^[3]

220

Corporate and Other [Member]

123

449

Goodwill impairment charge recorded from annual impairment test

^[3]

438

Vectren acquisition [Member]

^[3]

4,345

Goodwill impairment charge recorded from annual impairment test

819

867

106

(50)

(41)

CERC Corp [Member] | Customer Relationships [Member]

470

406

(32)

(27)

CERC Corp [Member] | Covenants Not To Compete [Member]

(4)

(3)

CERC Corp [Member] | Other [Member]

(14)

(11)

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

Goodwill impairment charge recorded from annual impairment test

746

Goodwill impairment charge recorded from annual impairment test

^[5]

110

Accumulated goodwill impairment charge recorded in 2012

252

Goodwill, Impairment Loss, Net of Tax

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

Goodwill impairment charge recorded from annual impairment test

Depreciation and amortization expense [Member]

Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)

^[6],[7]

Depreciation and amortization expense [Member] | CERC Corp [Member]

Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)

Non-utility cost of revenues [Member]

Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)

^[7]

$ 0

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

4,339

Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)

$ 17

[1]	The fair value of intangible assets acquired through acquisitions has been finalized. See Note 4.
[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 Statements of Consolidated Income.
[3]	This represents the allocation of goodwill to reportable segments from the Merger, changes from preliminary amounts previously reported and includes the final determination of fair value for each reportable segment. See Note 4.
[4]	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012. As of December 31, 2019, CenterPoint Energy and CERC identified a triggering event to perform an interim goodwill impairment test and recognized a goodwill impairment on their Energy Services reporting unit which is included in Goodwill impairment on CenterPoint Energy’s and CERC’s Consolidated Statements of Income.
[5]	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.
[6]	Includes $17 million for the year ended December 31, 2019 of amortization expense related to intangibles acquired in the Merger.
[7]	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the year ended December 31, 2019, has been finalized. See Note 4.

Equity (CenterPoint Energy)

12 Months Ended

Dec. 31, 2019

Stockholders' Equity Note [Abstract]

Equity (CenterPoint Energy) [Text Block]

Equity (CenterPoint Energy)

Dividends Declared and Paid (CenterPoint Energy)

CenterPoint Energy declared dividends on its Common Stock during 2019, 2018 and 2017 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
October 17, 2019	November 21, 2019	December 12, 2019	$	0.2875	$	144
July 31, 2019	August 15, 2019	September 12, 2019	0.2875		145
April 25, 2019	May 16, 2019	June 13, 2019	0.2875		144
Total 2019			$	0.8625	$	433

December 12, 2018	February 21, 2019	March 14, 2019	$	0.2875	$	144
October 23, 2018	November 15, 2018	December 13, 2018	0.2775		139
July 26, 2018	August 16, 2018	September 13, 2018	0.2775		120
April 26, 2018	May 17, 2018	June 14, 2018	0.2775		120
Total 2018			$	1.1200	$	523



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 13, 2017	February 15, 2018	March 8, 2018	$	0.2775	$	120
October 25, 2017	November 16, 2017	December 8, 2017	0.2675		116
July 27, 2017	August 16, 2017	September 8, 2017	0.2675		115
April 27, 2017	May 16, 2017	June 9, 2017	0.2675		115
January 5, 2017	February 16, 2017	March 10, 2017	0.2675		115
Total 2017			$	1.3475	$	581

CenterPoint Energy declared dividends on its Series A Preferred Stock during 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
July 31, 2019	August 15, 2019	September 3, 2019	$	30.6250	$	24
Total 2019			$	30.6250	$	24

December 12, 2018	February 15, 2019	March 1, 2019	$	32.1563	$	26
Total 2018			$	32.1563	$	26

CenterPoint Energy declared dividends on its Series B Preferred Stock during 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
October 17, 2019	November 15, 2019	December 2, 2019	$	17.5000	$	17
July 31, 2019	August 15, 2019	September 3, 2019	17.5000		17
April 25, 2019	May 15, 2019	June 3, 2019	17.5000		17
Total 2019			$	52.5000	$	51

December 12, 2018	February 15, 2019	March 1, 2019	$	17.5000	$	17
October 23, 2018	November 15, 2018	December 1, 2018	11.6667		11
Total 2018			$	29.1667	$	28

There were no Series A Preferred Stock or Series B Preferred Stock outstanding or dividends declared in 2017.

Dividend Requirement on Preferred Stock



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Series A Preferred Stock	$	49	$	18	$	—
Series B Preferred Stock	68		17		—
Total preferred stock dividend requirement	$	117	$	35	$	—

Series A Preferred Stock

On August 22, 2018, CenterPoint Energy completed the issuance of 800,000 shares of its Series A Preferred Stock, at a price of $1,000 per share, resulting in net proceeds of $790 million after issuance costs. The aggregate liquidation value of the Series A Preferred Stock is $800 million with a per share liquidation value of $1,000.

CenterPoint Energy used the net proceeds from the Series A Preferred Stock offering to fund a portion of the Merger and to pay related fees and expenses.

Dividends. The Series A Preferred Stock accrue cumulative dividends, calculated as a percentage of the stated amount per share, at a fixed annual rate of 6.125% per annum to, but excluding, September 1, 2023, and at an annual rate of three-month LIBOR plus a spread of 3.270% thereafter to be paid in cash if, when and as declared. If declared, prior to September 1, 2023, dividends are payable semi-annually in arrears on each March 1 and September 1, beginning on March 1, 2019, and, for the period commencing on September 1, 2023, dividends are payable quarterly in arrears each March 1, June 1, September 1 and December 1, beginning on December 1, 2023. Cumulative dividends earned during the applicable periods are presented on CenterPoint Energy’s Statements of Consolidated Income as Preferred stock dividend requirement.

Optional Redemption. On or after September 1, 2023, CenterPoint Energy may, at its option, redeem the Series A Preferred Stock, in whole or in part, at any time or from time to time, for cash at a redemption price of $1,000 per share, plus any accumulated and unpaid dividends thereon to, but excluding, the redemption date.

At any time within 120 days after the conclusion of any review or appeal process instituted by CenterPoint Energy, if any, following the occurrence of a ratings event, CenterPoint Energy may, at its option, redeem the Series A Preferred Stock in whole, but not in part, at a redemption price in cash per share equal to $1,020 (102% of the liquidation value of $1,000) plus an amount equal to all accumulated and unpaid dividends thereon to, but excluding, the redemption date, whether or not declared.

Ranking. The Series A Preferred Stock, with respect to anticipated dividends and distributions upon CenterPoint Energy’s liquidation or dissolution, or winding-up of CenterPoint Energy’s affairs, ranks or will rank:


•	senior to Common Stock and to each other class or series of capital stock established after the initial issue date of the Series A Preferred Stock that is expressly made subordinated to the Series A Preferred Stock;


•	on a parity with any class or series of capital stock established after the initial issue date of the Series A Preferred Stock that is not expressly made senior or subordinated to the Series A Preferred Stock, including the Series B Preferred Stock;


•	junior to any class or series of capital stock established after the initial issue date of the Series A Preferred Stock that is expressly made senior to the Series A Preferred Stock;


•	junior to all existing and future indebtedness (including indebtedness outstanding under CenterPoint Energy’s credit facilities, senior notes and commercial paper) and other liabilities with respect to assets available to satisfy claims against CenterPoint Energy; and


•	structurally subordinated to any existing and future indebtedness and other liabilities of CenterPoint Energy’s subsidiaries and capital stock of CenterPoint Energy’s subsidiaries held by third parties.

Voting Rights. Holders of the Series A Preferred Stock generally will not have voting rights. Whenever dividends on shares of Series A Preferred Stock have not been declared and paid for the equivalent of three or more semi-annual or six or more quarterly dividend periods (including, for the avoidance of doubt, the dividend period beginning on, and including, the original issue date and ending on, but excluding, March 1, 2019), whether or not consecutive, the holders of such shares of Series A Preferred Stock, voting together as a single class with holders of any and all other series of voting preferred stock (as defined in the Statement of Resolution for the Series A Preferred Stock) then outstanding, will be entitled at CenterPoint Energy’s next annual or special meeting of shareholders to vote for the election of a total of two additional members of CenterPoint Energy’s Board of Directors, subject to certain limitations. This right will terminate if and when all accumulated dividends have been paid in full and, upon such termination, the term of office of each director so elected will terminate at such time and the number of directors on CenterPoint Energy’s Board of Directors will automatically decrease by two, subject to the revesting of such rights in the event of each subsequent nonpayment.

Series B Preferred Stock

On October 1, 2018, CenterPoint Energy completed the issuance of 19,550,000 depositary shares, each representing a 1/20th interest in a share of its Series B Preferred Stock, at a price of $50 per depositary share, resulting in net proceeds of $950 million after issuance costs. The aggregate liquidation value of Series B Preferred Stock is $978 million with a per share liquidation value of $1,000. The amount issued included 2,550,000 depositary shares issued pursuant to the exercise in full of the option granted to the underwriters to purchase additional depositary shares.

CenterPoint Energy used the net proceeds from the offering of depositary shares, each representing a 1/20th interest in a share of its Series B Preferred Stock, to fund a portion of the Merger and to pay related fees and expenses.

Dividends. Dividends on the Series B Preferred Stock will be payable on a cumulative basis when, as and if declared at an annual rate of 7.00% on the liquidation value of $1,000 per share. CenterPoint Energy may pay declared dividends in cash or, subject to certain limitations, in shares of Common Stock, or in any combination of cash and shares of Common Stock on March 1, June 1, September 1 and December 1 of each year, commencing on December 1, 2018 and ending on, and including, September 1, 2021. Cumulative dividends earned during the applicable periods are presented on CenterPoint Energy’s Statements of Consolidated Income as Preferred stock dividend requirement.

Mandatory Conversion. Unless earlier converted or redeemed, each share of the Series B Preferred Stock will automatically convert on the mandatory conversion date, which is expected to be September 1, 2021, into not less than 30.5820 and not more than 36.6980 shares of Common Stock, subject to certain anti-dilution adjustments. Correspondingly, the conversion rate per depositary share will be not less than 1.5291 and not more than 1.8349 shares of Common Stock, subject to certain anti-dilution adjustments. The conversion rate will be determined based on a preceding 20-day volume-weighted-average-price of Common Stock.

The following table illustrates the conversion rate per share of the Series B Preferred Stock, subject to certain anti-dilution adjustments:



Applicable Market Value of the Common Stock		Conversion Rate per Share of Series B Preferred Stock
Greater than $32.6990 (threshold appreciation price)		30.5820 shares of Common Stock
Equal to or less than $32.6990 but greater than or equal to $27.2494		Between 30.5820 and 36.6980 shares of Common Stock, determined by dividing $1,000 by the applicable market value
Less than $27.2494 (initial price)		36.6980 shares of Common Stock

The following table illustrates the conversion rate per depositary share, subject to certain anti-dilution adjustments:



Applicable Market Value of the Common Stock		Conversion Rate per Depository Share
Greater than $32.6990 (threshold appreciation price)		1.5291 shares of Common Stock
Equal to or less than $32.6990 but greater than or equal to $27.2494		Between 1.5291 and 1.8349 shares of Common Stock, determined by dividing $50 by the applicable market value
Less than $27.2494 (initial price)		1.8349 shares of Common Stock

Optional Conversion of the Holder. Other than during a fundamental change conversion period, and unless CenterPoint Energy has redeemed the Series B Preferred Stock, a holder of the Series B Preferred Stock may, at any time prior to September 1, 2021, elect to convert such holder’s shares of the Series B Preferred Stock, in whole or in part, at the minimum conversion rate of 30.5820 shares of Common Stock per share of the Series B Preferred Stock (equivalent to 1.5291 shares of Common Stock per depositary share), subject to certain anti-dilution and other adjustments. Because each depositary share represents a 1/20th fractional interest in a share of the Series B Preferred Stock, a holder of depositary shares may convert its depositary shares only in lots of 20 depositary shares.

Fundamental Change Conversion. If a fundamental change occurs on or prior to September 1, 2021, holders of the Series B Preferred Stock will have the right to convert their shares of the Series B Preferred Stock, in whole or in part, into shares of Common Stock at the fundamental change conversion rate during the period beginning on, and including, the effective date of such fundamental change and ending on, and including, the date that is 20 calendar days after such effective date (or, if later, the date that is 20 calendar days after holders receive notice of such fundamental change, but in no event later than September 1, 2021). Holders who convert shares of the Series B Preferred Stock during that period will also receive a make-whole dividend amount comprised of a fundamental change dividend make-whole amount, and to the extent there is any, the accumulated dividend amount. Because each depositary share represents a 1/20th fractional interest in a share of the Series B Preferred Stock, a holder of depositary shares may convert its depositary shares upon a fundamental change only in lots of 20 depositary shares.

Ranking. The Series B Preferred Stock, with respect to anticipated dividends and distributions upon CenterPoint Energy’s liquidation or dissolution, or winding-up of CenterPoint Energy’s affairs, ranks or will rank:


•	senior to Common Stock and to each other class or series of capital stock established after the initial issue date of the Series B Preferred Stock that is expressly made subordinated to the Series B Preferred Stock;


•	on a parity with the Series A Preferred Stock and any class or series of capital stock established after the initial issue date that is not expressly made senior or subordinated to the Series B Preferred Stock;


•	junior to any class or series of capital stock established after the initial issue date that is expressly made senior to the Series B Preferred Stock;


•	junior to all existing and future indebtedness (including indebtedness outstanding under CenterPoint Energy’s credit facilities, senior notes and commercial paper) and other liabilities with respect to assets available to satisfy claims against CenterPoint Energy; and


•	structurally subordinated to any existing and future indebtedness and other liabilities of CenterPoint Energy’s subsidiaries and capital stock of CenterPoint Energy’s subsidiaries held by third parties.

Voting Rights. Holders of the Series B Preferred Stock generally will not have voting rights. Whenever dividends on shares of the Series B Preferred Stock have not been declared and paid for six or more dividend periods (including, for the avoidance of doubt, the dividend period beginning on, and including, the initial issue date and ending on, but excluding, December 1, 2018), whether or not consecutive, the holders of such shares of Series B Preferred Stock, voting together as a single class with holders of any and all other series of voting preferred stock then outstanding (as defined in the Statement of Resolution for the Series B Preferred Stock), will be entitled at CenterPoint Energy’s next annual or special meeting of shareholders to vote for the election of a total of two additional members of CenterPoint Energy’s Board of Directors, subject to certain limitations. This right will terminate if and when all accumulated and unpaid dividends have been paid in full and, upon such termination, the term of office of each director so elected will terminate at such time and the number of directors on CenterPoint Energy’s Board of Directors will automatically decrease by two, subject to the revesting of such rights in the event of each subsequent nonpayment.

Common Stock

On October 1, 2018, CenterPoint Energy completed the issuance of 69,633,027 shares of Common Stock at a price of $27.25 per share, for net proceeds of $1,844 million after issuance costs. The amount issued included 9,082,568 shares of Common Stock issued pursuant to the exercise in full of the option granted to the underwriters to purchase additional shares of Common Stock.

CenterPoint Energy used the net proceeds from the Common Stock offering to fund a portion of the Merger and to pay related fees and expenses.

Undistributed Retained Earnings

As of December 31, 2019 and 2018, CenterPoint Energy’s consolidated retained earnings balance includes undistributed earnings from Enable of $-0- and $31 million, respectively.

Accumulated Other Comprehensive Income (Loss)

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



	Year Ended December 31,
	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:
Remeasurement of pension and other postretirement plans	7			—			7			(19		)	—			1
Deferred loss from interest rate derivatives (1)	(3		)	(1		)	—			(19		)	(18		)	(1		)
Reclassified to earnings	1			—			—			—			—			—
Other comprehensive loss from unconsolidated affiliates	(1		)	—			—			—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—			1			—			1
Actuarial losses (2)	8			—			—			6			—			—
Tax benefit (expense)	(3		)	—			(2		)	6			4			(1		)
Net current period other comprehensive income (loss)	10			(1		)	5			(25		)	(14		)	—
Adoption of ASU 2018-02	—			—			—			(15		)	—			(1		)
Ending Balance	$	(98	)	$	(15	)	$	10		$	(108	)	$	(14	)	$	5

(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 Registrant’s respective Statements of Consolidated Income. Amounts are $1 million and less than $1 million for the years ended December 31, 2019 and 2018, respectively.

(2)

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

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Summary of Income Tax Contingencies [Table Text Block]

A reconciliation of CenterPoint Energy’s beginning and ending balance of unrecognized tax benefits, excluding interest and penalties, for 2019 is as follows:



	Year Ended December 31, 2019
	(in millions)
Balance, beginning of year	$	—
Unrecognized tax benefits assumed through the Merger	9
Decreases related to tax positions of prior years	(1		)
Balance, end of year	$	8

CenterPoint Energy had no unrecognized tax benefits for 2018 and 2017.

Income Tax Expense [Table Text Block]

The components of the Registrant’ income tax expense (benefit) were as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CenterPoint Energy
Current income tax expense:
Federal	$	48		$	89		$	32
State	21			9			9
Total current expense	69			98			41
Deferred income tax expense (benefit):
Federal	74			(25		)	(806		)
State	(5		)	73			36
Total deferred expense (benefit)	69			48			(770		)
Total income tax expense (benefit)	$	138		$	146		$	(729	)
Houston Electric
Current income tax expense:
Federal	$	84		$	109		$	70
State	20			18			19
Total current expense	104			127			89
Deferred income tax benefit:
Federal	(24		)	(38		)	(98		)
Total deferred benefit	(24		)	(38		)	(98		)
Total income tax expense (benefit)	$	80		$	89		$	(9	)
CERC - Continuing Operations
Current income tax expense (benefit):
Federal	$	—		$	(9	)	$	(31	)
State	7			—			(10		)
Total current expense (benefit)	7			(9		)	(41		)
Deferred income tax expense (benefit):
Federal	39			10			(249		)
State	(32		)	21			25
Total deferred expense (benefit)	7			31			(224		)
Total income tax expense (benefit)	$	14		$	22		$	(265	)
CERC - Discontinued Operations
Current income tax expense (benefit):
Federal	$	—		$	9		$	31
State	—			4			11
Total current expense (benefit)	—			13			42
Deferred income tax expense:
Federal	—			29			56
State	—			4			6
Total deferred expense	—			33			62
Total income tax expense	$	—		$	46		$	104

Reconciliation of Expected Federal Income Tax Expense to Actual [Table Text Block]

A reconciliation of income tax expense (benefit) using the federal statutory income tax rate to the actual income tax expense and resulting effective income tax rate is as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CenterPoint Energy (1) (2) (3)
Income before income taxes	$	929		$	514		$	1,063
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	195			108			372
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	36			22			26
State valuation allowance, net of federal income tax	(4		)	11			3
State law change, net of federal income tax	(21		)	32			—
Federal income tax rate reduction	—			—			(1,113		)
Excess deferred income tax amortization	(55		)	(24		)	—
Other, net	(13		)	(3		)	(17		)
Total	(57		)	38			(1,101		)
Total income tax expense (benefit)	$	138		$	146		$	(729	)
Effective tax rate	15		%	28		%	(69		)%
Houston Electric (4) (5) (6)
Income before income taxes	$	436		$	425		$	424
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	92			89			148
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	16			14			12
Federal income tax rate reduction	—			—			(158		)
Excess deferred income tax amortization	(21		)	(9		)	—
Other, net	(7		)	(5		)	(11		)
Total	(12		)	—			(157		)
Total income tax expense (benefit)	$	80		$	89		$	(9	)
Effective tax rate	18		%	21		%	(2		)%
CERC - Continuing Operations (7) (8) (9)
Income before income taxes	$	226		$	92		$	319
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	47			19			112
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	(12		)	5			6
State law change, net of federal income tax	(4		)	—			—
State valuation allowance, net of federal income tax	(4		)	11			3
Federal income tax rate reduction	—			—			(396		)
Goodwill impairment	8			—			—
Excess deferred income tax amortization	(18		)	(15		)	—
Tax basis balance sheet adjustment	—			—			11
Other, net	(3		)	2			(1		)
Total	(33		)	3			(377		)
Total income tax expense (benefit)	$	14		$	22		$	(265	)
Effective tax rate	6		%	24		%	(83		)%



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CERC - Discontinued Operations (9)
Income before income taxes	$	—		$	184		$	265
Federal statutory income tax rate	—		%	21		%	35		%
Expected federal income tax expense	—			39			93
Increase in tax expense resulting from:
State income tax expense, net of federal income tax	—			7			11
Total	—			7			11
Total income tax expense	$	—		$	46		$	104
Effective tax rate	—		%	25		%	39		%

(1)

Recognized a $55 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions, a $21 million net benefit for the impact of state law changes that resulted in the remeasurement of state deferred taxes in those jurisdictions, and $4 million net benefit for the reduction in valuation allowances on certain state net operating losses that are now expected to be realized.

(2)

Recognized a $32 million deferred tax expense due to state law changes that resulted in remeasurement of state deferred taxes in those jurisdictions. Also recorded an additional $11 million valuation allowance on certain state net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. These items are partially offset by $24 million of amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions beginning in 2018.


(3)	Recognized a $1.1 billion deferred tax benefit from the remeasurement of CenterPoint Energy’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.


(4)	Recognized $21 million of amortization of the net regulatory EDIT liability as decreed by regulators.


(5)	Recognized $9 million of amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions beginning in 2018.


(6)	Recognized a $158 million deferred tax benefit from the remeasurement of Houston Electric’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.

(7)

Recognized $18 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions, $4 million net benefit for the impact of state law changes that resulted in the remeasurement of state deferred taxes in those jurisdictions and $4 million net benefit for the reduction in valuation allowances on certain state net operating losses that are now expected to be realized.


(8)	Recorded an additional $11 million valuation allowance on certain state net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. This item is partially offset by $15 million of amortization of the net regulatory EDIT liability in certain jurisdictions as decreed by regulators beginning in 2018.

(9)

Recognized a $396 million deferred tax benefit from the remeasurement of CERC’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%. ASC 740 requires tax impacts of changes in tax laws or rates be reported in continuing operations. Therefore, CERC’s federal income tax benefit generated by the remeasurement of the ADFIT liability for Enable during 2017 and state law changes during 2016 associated with its investment in Enable are reported in continuing operations on CERC’s Statements of Consolidated Income. The ADFIT liability associated with CERC’s investment in Enable is reported as discontinued operations on CERC’s Consolidated Balance Sheets.

Tax Assets and Liabilities [Table Text Block]

The tax effects of temporary differences that give rise to significant portions of deferred tax assets and liabilities were as follows:



	December 31,
	2019			2018
	(in millions)
CenterPoint Energy
Deferred tax assets:
Benefits and compensation	$	152		$	160
Regulatory liabilities	447			356
Loss and credit carryforwards	111			84
Asset retirement obligations	89			62
Indexed debt securities derivative	34			—
Other	40			29
Valuation allowance	(25		)	(18		)
Total deferred tax assets	848			673
Deferred tax liabilities:
Property, plant and equipment	2,656			1,894
Investment in unconsolidated affiliates	1,010			987
Regulatory assets	344			395
Investment in marketable securities and indexed debt	586			478
Indexed debt securities derivative	—			27
Other	180			131
Total deferred tax liabilities	4,776			3,912
Net deferred tax liabilities	$	3,928		$	3,239
Houston Electric
Deferred tax assets:
Regulatory liabilities	$	195		$	205
Benefits and compensation	14			17
Asset retirement obligations	9			7
Other	7			12
Total deferred tax assets	225			241
Deferred tax liabilities:
Property, plant and equipment	1,129			1,087
Regulatory assets	126			177
Total deferred tax liabilities	1,255			1,264
Net deferred tax liabilities	$	1,030		$	1,023
CERC - Continuing Operations
Deferred tax assets:
Benefits and compensation	$	24		$	27
Regulatory liabilities	144			150
Loss and credit carryforwards	183			259
Asset retirement obligations	80			54
Other	23			20
Valuation allowance	(15		)	(18		)
Total deferred tax assets	439			492
Deferred tax liabilities:
Property, plant and equipment	821			773
Regulatory assets	45			41
Other	43			84
Total deferred tax liabilities	909			898
Net deferred tax liabilities	$	470		$	406

Supplemental Disclosure of Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2019

Supplemental Cash Flow Elements [Abstract]

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

The tables below provide supplemental disclosure of cash flow information:



	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	436	$	229	$	109	$	363	$	200	$	105	$	378	$	205	$	116
Income taxes (refunds), net	155		87		7		89		154		3		15		76		4
Non-cash transactions:
Accounts payable related to capital expenditures	236		117		86		201		124		80		144		104		56
Capital distribution associated with the Internal Spin (1)	—		—		28		—		—		1,473		—		—		—
ROU assets obtained in exchange for lease liabilities (2)	44		1		29		—		—		—		—		—		—


(1)	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.


(2)	Includes the transition impact of adoption of ASU 2016-02 Leases as of January 1, 2019. The Registrants elected not to recast comparative periods in the year of adoption as permitted by the standard.

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



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash and cash equivalents (1) (2)	$	241	$	216	$	2	$	4,231	$	335	$	14
Restricted cash included in Prepaid expenses and other current assets	30		19		—		46		34		11
Restricted cash included in Other	—		—		—		1		1		—
Total cash, cash equivalents and restricted cash shown in Statements of Consolidated Cash Flows	$	271	$	235	$	2	$	4,278	$	370	$	25

(1)

CenterPoint Energy’s Cash and cash equivalents as of December 31, 2018 included $3.9 billion of temporary investments resulting from the Merger financings. CenterPoint Energy recorded interest income of $22 million, $28 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on CenterPoint Energy’s Statements of Consolidated Income. See Notes 13 and 14 for further details related to the Merger financings.

(2)

Houston Electric’s Cash and cash equivalents as of December 31, 2019 and 2018 included $216 million and $335 million, respectively, of cash related to the Bond Companies. Houston Electric recorded interest income of $9 million, $4 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on Houston Electric’s Statement of Consolidated Inc

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

12 Months Ended

Dec. 31, 2019

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

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:



	December 31, 2019						December 31, 2018
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	481		$	—		$	(1	)	$	114
Weighted average interest rate	1.98		%	1.98		%	2.42		%	2.42		%

(1)

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

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



	Year Ended December 31,
	2019				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Interest income (expense), net (1)	$	18	$	4	$	1	$	—	$	2	$	—


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

Amounts charged for these services are included primarily in Operation and maintenance expenses and amounts billed for natural gas sales are included in Non-utility revenues were as follows:



	Year Ended December 31,
	2019					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	177		$	141	$	190		$	147	$	188		$	128
Net affiliate service charges (billings)	(8		)	8		(17		)	17		(9		)	9
Pipeline construction and repair service charges (1)	—			4		—			—		—			—
Natural gas sales (2)	—			1		—			—		—			—


(1)	Represents charges from Infrastructure Services to CERC’s NGD for the period February 1, 2019 through December 31, 2019.


(2)	Represents sales to Indiana Electric from CES for the period February 1, 2019 through December 31, 2019.

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



	Year Ended December 31,
	2019				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	376	$	120	$	209	$	360	$	180	$	601
Cash contribution from parent	590		129		200		960		—		38
Capital distribution to parent associated with the Internal Spin (1)	—		28		—		1,473		—		—

(1)

The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.

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

12 Months Ended

Dec. 31, 2019

Indexed Debt Securities [Abstract]

Summarized Financial Information on Investment in Time Warner Securities and Indexed Debt Security Obligation [Table Text Block]

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 Statements of Consolidated Income.

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



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

The following table sets forth summarized financial information regarding CenterPoint Energy’s investment in ZENS-Related Securities and each component of CenterPoint Energy’s ZENS obligation.



	ZENS-Related Securities			Debt Component of ZENS			Derivative Component of ZENS
	(in millions)
Balance as of December 31, 2016	$	953		$	114		$	717
Accretion of debt component of ZENS	—			27			—
2% interest paid	—			(17		)	—
Distribution to ZENS holders	—			(2		)	—
Gain on indexed debt securities	—			—			(49		)
Gain on ZENS-Related Securities	7			—			—
Balance as of December 31, 2017	960			122			668
Accretion of debt component of ZENS	—			21			—
2% interest paid	—			(17		)	—
Sale of ZENS-Related Securities	(398		)	—			—
Distribution to ZENS holders	—			(102		)	(46		)
Gain on indexed debt securities	—			—			(21		)
Loss on ZENS-Related Securities	(22		)	—			—
Balance as of December 31, 2018	540			24			601
Accretion of debt component of ZENS	—			17			—
2% interest paid	—			(17		)	—
Distribution to ZENS holders	—			(5		)	—
Loss on indexed debt securities	—			—			292
Gain on ZENS-Related Securities	282			—			—
Balance as of December 31, 2019	$	822		$	19		$	893

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

3 Months Ended

12 Months Ended

Feb. 01, 2019

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Dividends declared per share

$ 0.86

$ 1.1200

$ 1.35

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

$ 5,164

$ 867

$ 5,164

$ 867

Business Combination, Separately recognized Transactions, Additional Disclosures [Abstract]

$ 0

$ 3,230

$ 2,742

$ 2,798

$ 3,531

$ 3,036

$ 2,212

$ 2,186

$ 3,155

12,301

10,589

9,614

Non-utility cost of revenues [Member]

791

368

1,792

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

Depreciation and amortization expense [Member]

^[1]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

^[1],[2]

$ 13

Cash paid per share of Vectren common stock at closing of the Merger

$ 6,000

$ 5,982

$ 72.00

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]

Property, plant and equipment, net

$ 16

Other current assets

577

5,147

Identifiable intangibles

297

338

Other assets

141

Total assets acquired

6,516

Current liabilities

648

Total liabilities assumed

938

Other liabilities

886

Long-term debt

2,401

4,873

Net assets acquired

1,643

4,339

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

$ 6,000

5,982

Business Combination, Separately recognized Transactions, Additional Disclosures [Abstract]

297

2,729

Business Acquisition, Pro Forma Information [Abstract]

190

Operating Revenue

12,547

13,282

Net Income (1)

812

^[3]

458

^[4]

Vectren [Member] | Operation And Maintenance Expense [Member]

Severance expense related to the Merger

$ 61

102

Business Combination, Separately recognized Transactions, Additional Disclosures [Abstract]

Integration costs

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

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

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

$ 17

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

24 years

Vectren [Member] | Customer Relationships [Member]

$ 12

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

18 years

Vectren [Member] | Construction backlog [Member]

$ 200

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

1 year

Vectren [Member] | Trade Names [Member]

$ 27

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

10 years

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

$ 58

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

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

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill [Abstract]

Vectren [Member] | Stub period [Member]

$ 16

Dividends declared per share

$ 0.41145

Vectren acquisition [Member]

Cash payments towards outstanding share-based awards

$ 78

Share-based award liability recorded

Incremental share-based awards expense recorded

Utility pipeline construction company [Member]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]

Identifiable intangibles

$ 6

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

Business Acquisition, Pro Forma Information [Abstract]

Transaction costs associated with the Merger

$ 37

[1]	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the year ended December 31, 2019, has been finalized. See Note 4.
[2]	Includes $17 million for the year ended December 31, 2019 of amortization expense related to intangibles acquired in the Merger.
[3]	Pro forma net income was adjusted to exclude $37 million of Vectren Merger-related transaction costs incurred in 2019.
[4]	Pro forma net income was adjusted to include $37 million of Vectren Merger-related transaction costs incurred in 2019.

Stock-Based Incentive Compensation Plans and Employee Benefit Plans Plan Assets (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Defined Contribution Plan, Cost

^[1]

$ 58

$ 43

$ 41

Postemployment Benefits, Period Expense

Benefit expense related to deferred compensation plans

$ 3

Non-qualified Pension Plan [Member]

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

$ 7

Pension Plan [Member]

3.20%

^[2]

4.35%

^[2]

3.65%

Obligation To Return Cash Received As Collateral From Securities Lending,

$ 2,005

$ 1,516

$ 1,801

(61)

(77)

Defined Benefits Plan, Fair Value Of Plan Assets, Excluding Investments Measured at Net Asset Value

1,339

860

Defined Benefit Plan, Contribution by Employer, Qualified Plan

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

109

$ 69

Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]

180

178

180

181

177

$ 824

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Postretirement Benefits [Member]

3.25%

^[3]

4.35%

^[3]

3.60%

$ 128

$ 114

$ 120

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]

$ 112

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Obligation To Return Cash Received As Collateral From Securities Lending,

$ 564

442

(61)

(77)

Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Obligation To Return Cash Received As Collateral From Securities Lending,

775

418

Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Obligation To Return Cash Received As Collateral From Securities Lending,

U.S. Equity [Member] | Pension Plan [Member]

U.S. Equity [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

U.S. Equity [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

U.S. Equity [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Cash and Cash Equivalents [Member] | Pension Plan [Member]

Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

(7)

Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

(7)

Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Investment grade or above [Member] | Pension Plan [Member]

Investment grade or above [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

699

368

Investment grade or above [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Investment grade or above [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

699

368

Cash received as collateral from securities [Member] | Pension Plan [Member]

Cash received as collateral from securities [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Cash received as collateral from securities [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Cash received as collateral from securities [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

U.S. treasuries [Member] | Pension Plan [Member]

U.S. treasuries [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

232

196

U.S. treasuries [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

232

196

U.S. treasuries [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Mortgage backed securities [Member] | Pension Plan [Member]

Mortgage backed securities [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Mortgage backed securities [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Mortgage backed securities [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Asset backed securities [Member] | Pension Plan [Member]

Asset backed securities [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Asset backed securities [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Asset backed securities [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Municipal bonds [Member] | Pension Plan [Member]

Municipal bonds [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Municipal bonds [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

Municipal bonds [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Mutual funds [Member] | Pension Plan [Member]

Mutual funds [Member] | Postretirement Benefits [Member]

^[4]

270

167

Mutual funds [Member] | International Equity [Member] | Pension Plan [Member]

$ 128

$ 114

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

31.00%

85.00%

Mutual funds [Member] | International Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

8.00%

7.00%

Mutual funds [Member] | U.S. Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

49.00%

15.00%

Mutual funds [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

21.00%

19.00%

Mutual funds [Member] | Real Estate Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

1.00%

0.00%

Mutual funds [Member] | Fixed Income Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

19.00%

0.00%

Mutual funds [Member] | Fixed Income Funds [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

71.00%

74.00%

Mutual funds [Member] | Emerging Market Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

34.00%

Mutual funds [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

Mutual funds [Member] | Fair Value, Inputs, Level 1 [Member] | Postretirement Benefits [Member]

$ 270

$ 167

Mutual funds [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

128

114

Mutual funds [Member] | Fair Value, Inputs, Level 2 [Member] | Postretirement Benefits [Member]

Mutual funds [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Mutual funds [Member] | Fair Value, Inputs, Level 3 [Member] | Postretirement Benefits [Member]

International government bonds [Member] | Pension Plan [Member]

International government bonds [Member] | Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]

International government bonds [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]

International government bonds [Member] | Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]

Common Collective Trust Funds [Member] | Pension Plan [Member]

Common Collective Trust Funds [Member] | International Equity [Member] | Pension Plan [Member]

^[4],[5]

$ 666

$ 656

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

29.00%

41.00%

Common Collective Trust Funds [Member] | U.S. Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

51.00%

5.00%

Common Collective Trust Funds [Member] | Real Estate Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

6.00%

0.00%

Common Collective Trust Funds [Member] | Fixed Income Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

14.00%

54.00%

Common Collective Trust Funds [Member] | Emerging Market Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

4.00%

Benefit Obligation [Member]

Postemployment benefit obligations

$ 11

Other non-qualified plans benefit obligations deferred compensation

Benefit obligations related to split-dollar life insurance arrangements

$ 32

Minimum [Member] | U.S. Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

19.00%

Minimum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

13.00%

Minimum [Member] | International Developed Market Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

8.00%

Minimum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

3.00%

Minimum [Member] | Real Estate Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

3.00%

Minimum [Member] | Fixed Income [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

52.00%

Minimum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

69.00%

Minimum [Member] | Cash and Cash Equivalents [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

0.00%

Minimum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

0.00%

Maximum [Member] | U.S. Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

29.00%

Maximum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

23.00%

Maximum [Member] | International Developed Market Equity [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

18.00%

Maximum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

13.00%

Maximum [Member] | Real Estate Funds [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

9.00%

Maximum [Member] | Fixed Income [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

62.00%

Maximum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

79.00%

Maximum [Member] | Cash and Cash Equivalents [Member] | Pension Plan [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

2.00%

Maximum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

2.00%

Common Stock [Member] | CenterPoint Energy [Member]

Number of Common stock held by the savings plan (in shares)

11,051,800

Percentage of investment in common stocks (in hundredths)

13.00%

Defined Contribution Plan, Maximum Limit Of Account Balance In Company Stock, Percentage

25.00%

Defined Contribution Plan, Cost

^[1]

$ 18

Postemployment Benefits, Period Expense

Benefit expense related to deferred compensation plans

$ 1

Houston Electric [Member] | Non-qualified Pension Plan [Member]

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

Houston Electric [Member] | Pension Plan [Member]

Defined Benefit Plan, Contribution by Employer, Qualified Plan

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

$ 0

Houston Electric [Member] | Postretirement Benefits [Member]

3.25%

^[3]

4.35%

^[3]

3.60%

$ 101

$ 89

$ 93

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]

$ 54

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Houston Electric [Member] | Mutual funds [Member] | Postretirement Benefits [Member]

Houston Electric [Member] | Mutual funds [Member] | International Equity [Member] | Postretirement Benefits [Member]

$ 101

$ 89

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

8.00%

7.00%

Houston Electric [Member] | Mutual funds [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

21.00%

19.00%

Houston Electric [Member] | Mutual funds [Member] | Fixed Income Funds [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

71.00%

74.00%

Houston Electric [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 1 [Member] | Postretirement Benefits [Member]

Houston Electric [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 2 [Member] | Postretirement Benefits [Member]

$ 101

$ 89

Houston Electric [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 3 [Member] | Postretirement Benefits [Member]

Houston Electric [Member] | Benefit Obligation [Member]

Postemployment benefit obligations

Other non-qualified plans benefit obligations deferred compensation

Benefit obligations related to split-dollar life insurance arrangements

$ 1

Houston Electric [Member] | Minimum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

13.00%

Houston Electric [Member] | Minimum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

3.00%

Houston Electric [Member] | Minimum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

69.00%

Houston Electric [Member] | Minimum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

0.00%

Houston Electric [Member] | Maximum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

23.00%

Houston Electric [Member] | Maximum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

13.00%

Houston Electric [Member] | Maximum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

79.00%

Houston Electric [Member] | Maximum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

2.00%

Houston Electric [Member] | Common Stock [Member] | CenterPoint Energy [Member]

Number of Common stock held by the savings plan (in shares)

11,051,800

Percentage of investment in common stocks (in hundredths)

13.00%

Defined Contribution Plan, Maximum Limit Of Account Balance In Company Stock, Percentage

25.00%

Defined Contribution Plan, Cost

^[1]

$ 18

Postemployment Benefits, Period Expense

Benefit expense related to deferred compensation plans

$ 0

CERC Corp [Member] | Non-qualified Pension Plan [Member]

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

CERC Corp [Member] | Pension Plan [Member]

Defined Benefit Plan, Contribution by Employer, Qualified Plan

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

$ 0

CERC Corp [Member] | Postretirement Benefits [Member]

3.25%

^[3]

4.35%

^[3]

3.60%

$ 27

$ 25

$ 26

Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year

Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]

$ 30

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

CERC Corp [Member] | Mutual funds [Member] | Postretirement Benefits [Member]

CERC Corp [Member] | Mutual funds [Member] | International Equity [Member] | Postretirement Benefits [Member]

$ 27

$ 25

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

7.00%

6.00%

CERC Corp [Member] | Mutual funds [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

24.00%

21.00%

CERC Corp [Member] | Mutual funds [Member] | Fixed Income Funds [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage

69.00%

73.00%

CERC Corp [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 1 [Member] | Postretirement Benefits [Member]

CERC Corp [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 2 [Member] | Postretirement Benefits [Member]

$ 27

$ 25

CERC Corp [Member] | Mutual funds [Member] | Fair Value, Inputs, Level 3 [Member] | Postretirement Benefits [Member]

CERC Corp [Member] | Benefit Obligation [Member]

Postemployment benefit obligations

Other non-qualified plans benefit obligations deferred compensation

Benefit obligations related to split-dollar life insurance arrangements

$ 0

CERC Corp [Member] | Minimum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

15.00%

CERC Corp [Member] | Minimum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

2.00%

CERC Corp [Member] | Minimum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

68.00%

CERC Corp [Member] | Minimum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

0.00%

CERC Corp [Member] | Maximum [Member] | U.S. Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

25.00%

CERC Corp [Member] | Maximum [Member] | International Developed Market Equity [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

12.00%

CERC Corp [Member] | Maximum [Member] | Fixed Income [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

78.00%

CERC Corp [Member] | Maximum [Member] | Cash and Cash Equivalents [Member] | Postretirement Benefits [Member]

Defined Benefit Plan, Plan Assets, Target Allocation, Percentage

2.00%

CERC Corp [Member] | Common Stock [Member] | CenterPoint Energy [Member]

Number of Common stock held by the savings plan (in shares)

11,051,800

Percentage of investment in common stocks (in hundredths)

13.00%

Defined Contribution Plan, Maximum Limit Of Account Balance In Company Stock, Percentage

25.00%

[1]

Amounts presented in the table above are included in Operation and maintenance expense in the Registrants’ respective Statements of Consolidated Income and shown prior to any amounts capitalized.

[2]

The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.

[3]

The discount rate assumption was determined by matching the projected cash flows of the plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.

[4]

The amounts invested in mutual funds and common collective trust funds were allocated as follows:



	As of December 31,
	2019				2018
	Mutual Funds		Common Collective Trust Funds		Mutual Funds		Common Collective Trust Funds
International equities (1)	31	%	29	%	85	%	41	%
U.S. equities	49	%	51	%	15	%	5	%
Real estate	1	%	6	%	—	%	—	%
Fixed income	19	%	14	%	—	%	54	%

(1)

The amounts invested in international equities for 2018 include allocations of 34% in mutual funds and 4% in common collective trust funds,which were previously reported as allocations in emerging market equities.

[5]

Represents investments in common collective trust funds.

Stock-Based Incentive Compensation Plans and Employee Benefit Plans

12 Months Ended

Dec. 31, 2019

Disclosure of Stock-Based Incentive Compensation Plans and Employee Benefit Plans [Abstract]

Stock-Based Incentive Compensation Plans and Employee Benefit Plans [Text Block]

Stock-Based Incentive Compensation Plans and Employee Benefit Plans

(a) Stock-Based Incentive Compensation Plans (CenterPoint Energy)

CenterPoint Energy has LTIPs that provide for the issuance of stock-based incentives, including stock options, performance awards, restricted stock unit awards and restricted and unrestricted stock awards to officers, employees and non-employee directors. Approximately 14 million shares of Common Stock are authorized under these plans for awards. CenterPoint Energy issues new shares of its Common Stock to satisfy stock-based payments related to LTIPs. Equity awards are granted to employees without cost to the participants.

Compensation costs for the performance and stock unit awards granted under LTIPs are measured using fair value and expected achievement levels on the grant date. For performance awards with operational goals, the achievement levels are revised as goals are evaluated. The fair value of awards granted to employees is based on the closing stock price of CenterPoint Energy’s Common Stock on the grant date. The compensation expense is recorded on a straight-line basis over the vesting period. Forfeitures are estimated on the date of grant based on historical averages and estimates are updated periodically throughout the vesting period.

The performance awards granted in 2019, 2018 and 2017 are distributed based upon the achievement of certain objectives over a three-year performance cycle. The stock unit awards granted in 2019, 2018 and 2017 are service based. The stock unit awards generally vest at the end of a three-year period, provided, however, that stock unit awards granted to non-employee directors vested at the end of a one-year period (for awards granted in 2017) or vested immediately upon grant (for awards granted in 2019 and 2018). Upon vesting, both the performance and stock unit awards are issued to the participants along with the value of dividend equivalents earned over the performance cycle or vesting period.

The following table summarizes CenterPoint Energy’s expenses related to LTIPs for 2019, 2018 and 2017:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
LTIP Compensation expense (1)	$	28	$	26	$	21
Income tax benefit recognized	7		6		8
Actual tax benefit realized for tax deductions	12		5		6


(1)	Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income and shown prior to any amounts capitalized.

The following tables summarize CenterPoint Energy’s LTIP activity for 2019:



	Year Ended December 31, 2019
	Shares (Thousands)		Weighted-Average Grant Date Fair Value		Remaining Average Contractual Life (Years)	Aggregate Intrinsic Value (2) (Millions)
Performance Awards (1)
Outstanding and non-vested as of December 31, 2018	3,818		$	23.91
Granted	1,413		31.16
Forfeited or canceled	(825	)	24.78
Vested and released to participants	(1,074	)	18.97
Outstanding and non-vested as of December 31, 2019	3,332		$	28.36	1.1	$	53

Stock Unit Awards
Outstanding and non-vested as of December 31, 2018	1,060		$	24.08
Granted	470		31.07
Forfeited or canceled	(131	)	27.95
Vested and released to participants	(433	)	20.72
Outstanding and non-vested as of December 31, 2019	966		$	28.46	1.2	$	26


(1)	Reflects maximum performance achievement.


(2)	Reflects the impact of current expectations of achievement and stock price.

The weighted average grant date fair values per unit of awards granted were as follows for 2019, 2018 and 2017:



	Year Ended December 31,
	2019		2018		2017
	(In millions, except for per unit amounts)
Performance Awards
Weighted-average grant date fair value per unit of awards granted	$	31.16	$	26.74	$	26.64
Total intrinsic value of awards received by participants	36		12		7
Vested grant date fair value	20		9		5

Stock Unit Awards
Weighted-average grant date fair value per unit of awards granted	$	31.07	$	26.62	$	26.77
Total intrinsic value of awards received by participants	15		9		9
Vested grant date fair value	9		7		7

As of December 31, 2019, there was $34 million of total unrecognized compensation cost related to non-vested performance and stock awards which is expected to be recognized over a weighted-average period of 1.7 years.

(b) Pension Benefits (CenterPoint Energy)

CenterPoint Energy maintains a non-contributory qualified defined benefit pension plan covering eligible employees, with benefits determined using a cash balance formula. In addition to the non-contributory qualified defined benefit pension plan, CenterPoint Energy maintains unfunded non-qualified benefit restoration plans which allow participants to receive the benefits to which they would have been entitled under CenterPoint Energy’s non-contributory qualified pension plan except for federally mandated limits on qualified plan benefits or on the level of compensation on which qualified plan benefits may be calculated.

As a result of the Merger, CenterPoint Energy now also maintains three additional qualified defined benefit pension plans which are closed to new participants and a non-qualified supplemental retirement plan. The defined benefit pension plans cover eligible full-time regular employees and retirees of Vectren and are primarily non-contributory.

CenterPoint Energy’s net periodic cost includes the following components relating to pension, including the non-qualified benefit plans:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
Service cost (1)	$	40		$	37		$	36
Interest cost (2)	96			79			89
Expected return on plan assets (2)	(105		)	(107		)	(97		)
Amortization of prior service cost (2)	9			9			9
Amortization of net loss (2)	52			43			58
Settlement cost (2) (3)	2			—			—
Curtailment gain (2) (4)	(1		)	—			—
Net periodic cost	$	93		$	61		$	95


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


(2)	Amounts presented in the table above are included in Other, net in CenterPoint Energy’s 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. In 2019, CenterPoint Energy recognized a non-cash settlement cost 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 2019, CenterPoint Energy recognized a pension curtailment gain related to employees who were terminated after the Merger closed.

CenterPoint Energy used the following assumptions to determine net periodic cost relating to pension benefits:



	Year Ended December 31,
	2019		2018		2017
Discount rate	4.35	%	3.65	%	4.15	%
Expected return on plan assets	6.00		6.00		6.00
Rate of increase in compensation levels	4.60		4.45		4.50

In determining net periodic benefit cost, CenterPoint Energy uses fair value, as of the beginning of the year, as its basis for determining expected return on plan assets.

The following table summarizes changes in the benefit obligation, plan assets, the amounts recognized in the Consolidated Balance Sheets as well as the key assumptions of CenterPoint Energy’s pension plans. The measurement dates for plan assets and obligations were December 31, 2019 and 2018.



	December 31,
	2019			2018
	(in millions, except for actuarial assumptions)
Change in Benefit Obligation
Benefit obligation, beginning of year	$	2,013		$	2,225
Plan obligations assumed in Merger	332			—
Service cost	40			37
Interest cost	96			79
Benefits paid	(244		)	(201		)
Actuarial (gain) loss (1)	216			(127		)
Plan amendment	1			—
Curtailment	(1		)	—
Benefit obligation, end of year	2,453			2,013
Change in Plan Assets
Fair value of plan assets, beginning of year	1,516			1,801
Plan assets assumed in Merger	286			—
Employer contributions	109			69
Benefits paid	(244		)	(201		)
Actual investment return	338			(153		)
Fair value of plan assets, end of year	2,005			1,516
Funded status, end of year	$	(448	)	$	(497	)

Amounts Recognized in Balance Sheets
Current liabilities-other	$	(8	)	$	(7	)
Other liabilities-benefit obligations	(440		)	(490		)
Net liability, end of year	$	(448	)	$	(497	)
Actuarial Assumptions
Discount rate (2)	3.20		%	4.35		%
Expected return on plan assets (3)	5.75			6.00
Rate of increase in compensation levels	4.95			4.60
Interest crediting rate	3.25			3.75


(1)	Significant sources of loss for 2019 include the decrease in discount rate from 4.35% to 3.20%. Significant sources of gain for 2018 include the increase in discount rate from 3.65% to 4.35% and the mortality projection scale change from MP2017 to MP2018.


(2)	The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.


(3)	The expected rate of return assumption was developed using the targeted asset allocation of CenterPoint Energy’s plans and the expected return for each asset class.

The following table displays pension benefits related to CenterPoint Energy’s pension plans that have accumulated benefit obligations in excess of plan assets:



	December 31,
	2019				2018
	Pension (Qualified)		Pension (Non-qualified)		Pension (Qualified)		Pension (Non-qualified)
	(in millions)
Accumulated benefit obligation	$	2,352	$	68	$	1,930	$	61
Projected benefit obligation	2,385		68		1,952		61
Fair value of plan assets	2,005		—		1,516		—

The accumulated benefit obligation for all defined benefit pension plans on CenterPoint Energy’s Consolidated Balance Sheets was $2,420 million and $1,991 million as of December 31, 2019 and 2018, respectively.

Multi-employer Pension Plan

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.

Expense is recognized as payments are accrued for work performed or when withdrawal liabilities are probable and estimable. Expense associated with multi-employer plans of $52 million during the year ended December 31, 2019. During 2019, CenterPoint Energy made contributions to these multi-employer plans on behalf of employees that participate in approximately 215 local unions. Contracts with these unions are negotiated with trade agreements through two primary contractor associations. These trade agreements have varying expiration dates ranging from 2020 through 2022. The average contribution related to these local unions was less than $1 million, and the largest contribution was approximately $5 million. Multiple unions can contribute to a single multi-employer plan. CenterPoint Energy made contributions to at least 72 plans in 2019, eight of which are considered significant plans based on, among other things, the amount of the contributions, the number of employees participating in the plan, and the funded status of the plan.

CenterPoint Energy’s participation in the significant plans is outlined in the following table. The EIN / Pension Plan Number column provides the EIN and three-digit pension plan numbers. The most recent Pension Protection Act Zone Status available in 2019 is for the plan year end at January 31, 2019 for the Central Pension Fund, May 31, 2019 for the Indiana Pension Laborers Fund, December 31, 2018 for the Pipeline Industry Benefit Fund, December 31, 2018 for the Laborers District Council & Contractors’ Pension Fund of Ohio, April 30, 2019 for the Ohio Operating Engineers Pension Fund, April 30, 2019 for the Operating Engineers Local 324 Fringe Benefit Fund, December 31, 2018 for the Minnesota Laborers Pension Fund, and December 31, 2018 for the Laborers’ Combined Fund of Western Pennsylvania. Generally, plans in the red zone are less than 65% funded, plans in the yellow zone are less than 80% funded and plans in the green zone are at least 80% funded. The FIP/RP Status Pending / Implemented column indicates plans for which a FIP or RP is either pending or has been implemented. The multi-employer contributions listed in the table below are CenterPoint Energy’s multi-employer contributions made in 2019.

Federal law requires pension plans in endangered status to adopt a FIP and plans in critical status to adopt a RP aimed at

restoring the financial health of the plan. In December 2014, the Multi-employer Pension Reform Act of 2014 was passed and permanently extended the Pension Protection Act of 2006 multi-employer plan critical and endangered status funding rules, among other things, including providing a provision for a plan sponsor to suspend or reduce benefit payments to preserve plans in critical and declining status.

Pension Protection Act Zone Status

Multi-employer Contributions

Pension Fund

EIN/Pension

Plan Number

2019

FIP/RP Status Pending/Implemented

2019

Surcharge Imposed

(in millions)

Central Pension Fund

36-6052390-001

Green

Indiana Laborers Pension Fund

35-6027150-001

Green

Pipeline Industry Benefit Fund

73-0742835-001

Green

Laborers District Fund of Ohio

31-6129964-001

Green

Ohio Operating Engineers Pension Fund

31-6129968-001

Green

Operating Engineers Local #324 Fund (1)

38-1900637-001

Red

Implemented

Minnesota Laborers Pension Fund

41-6159599-001

Green

Laborers’ Combined Fund of Western PA (2)

25-6135576-001

Red

Implemented

Other

Total Contributions

(1)

The Operating Engineers Local #324 Fringe Benefits Fund was certified to be in “critical” status for the plan year ending April 30, 2019. In an effort to improve the plan’s funding situation, on March 17, 2011, the trustees adopted a plan amendment, which reduced benefit accruals and eliminated some ancillary benefits, and adopted an RP that will be effective from May 1, 2013 through April 30, 2023 or until the plan is no longer in critical status. On April 27, 2015, the trustees updated the RP to change the annual standard for meeting the requirements of the RP. The trustees further updated the RP on January 29, 2019. The annual standard is that actuarial projections updated for each year show the fund is expected to remain solvent for a 20-year projection period.


(2)	The Laborers’ Combined Fund of Western Pennsylvania was previously deemed in critical status. The trustees adopted a FIP that is scheduled to run through December 31, 2020 and provided for changes in adjustable benefits and increases in the employer contribution rate.

While not considered significant to CenterPoint Energy, there are four plans in red zone status receiving CenterPoint Energy contributions. There are also five other plans where CenterPoint Energy contributions exceed 5% of each plan’s total contributions; however, none of these plans are considered significant to CenterPoint Energy.

On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Purchase Agreement to sell the businesses within its Infrastructure Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23. As a result, CenterPoint Energy will no longer participate in the multi-employer pension plans discussed above.

CenterPoint Energy provides certain healthcare and life insurance benefits for eligible retired employees on both a contributory and non-contributory basis. The Registrants’ employees (other than employees of Vectren and its subsidiaries) who were hired before January 1, 2018 and who have met certain age and service requirements at retirement, as defined in the plans, are eligible to participate in these benefit plans. Employees hired on or after January 1, 2018 are not eligible for these benefits, except that such employees represented by IBEW Local Union 66 are eligible to participate in certain of the benefits, subject to the applicable age and service requirements. With respect to retiree medical and prescription drug benefits, employees represented by the IBEW Local Union 66 who retire on or after January 1, 2017, and their dependents, receive any such benefits exclusively through the NECA/IBEW Family Medical Care Plan pursuant to the terms of the renegotiated collective bargaining agreement entered into in May 2016. Houston Electric and CERC are required to fund a portion of their obligations in accordance with rate orders. All other obligations are funded on a pay-as-you-go basis.

As a result of the Merger, CenterPoint Energy now maintains an additional postretirement benefit plan. 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.

Postretirement benefits are accrued over the active service period of employees. The net postretirement benefit cost includes the following components:



	Year Ended December 31,
	2019									2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	3		$	1		$	1		$	2		$	—		$	1		$	2		$	1		$	1
Interest cost (2)	15			7			5			13			8			4			16			9			5
Expected return on plan assets (2)	(5		)	(4		)	(1		)	(5		)	(4		)	(1		)	(5		)	(4		)	(1		)
Amortization of prior service cost (credit) (2)	(5		)	(6		)	1			(5		)	(5		)	1			(5		)	(6		)	1
Net postretirement benefit cost (credit)	$	8		$	(2	)	$	6		$	5		$	(1	)	$	5		$	8		$	—		$	6


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


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

The following assumptions were used to determine net periodic cost relating to postretirement benefits:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
Discount rate	3.20	%	3.20	%	3.20	%	3.60	%	3.60	%	3.60	%	4.15	%	4.15	%	4.15	%
Expected return on plan assets	4.60		4.70		4.15		4.55		4.75		3.85		4.50		4.75		3.60

The following table summarizes changes in the benefit obligation, plan assets, the amounts recognized in consolidated balance sheets and the key assumptions of the postretirement plans. The measurement dates for plan assets and benefit obligations were December 31, 2019 and 2018.



	December 31,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Change in Benefit Obligation
Benefit obligation, beginning of year	$	331		$	166		$	110		$	386		$	225		$	109
Plan obligations assumed in Merger	37			—			—			—			—			—
Service cost	3			1			1			2			—			1
Interest cost	15			7			5			13			8			4
Participant contributions	8			2			4			7			2			4
Benefits paid	(26		)	(13		)	(8		)	(25		)	(13		)	(9		)
Plan amendment	9			3			5			—			—			—
Actuarial (gain) loss (1)	(21		)	(4		)	(15		)	(52		)	(56		)	1
Benefit obligation, end of year	356			162			102			331			166			110
Change in Plan Assets
Fair value of plan assets, beginning of year	114			89			25			120			93			26
Employer contributions	17			10			3			14			9			4
Participant contributions	8			2			4			7			2			4
Benefits paid	(26		)	(13		)	(8		)	(25		)	(13		)	(9		)
Actual investment return	15			13			3			(2		)	(2		)	—
Fair value of plan assets, end of year	128			101			27			114			89			25
Funded status, end of year	$	(228	)	$	(61	)	$	(75	)	$	(217	)	$	(77	)	$	(85	)
Amounts Recognized in Balance Sheets
Current liabilities-other	$	(8	)	$	—		$	(3	)	$	(6	)	$	—		$	(3	)
Other liabilities-benefit obligations	(220		)	(61		)	(72		)	(211		)	(77		)	(82		)
Net liability, end of year	$	(228	)	$	(61	)	$	(75	)	$	(217	)	$	(77	)	$	(85	)
Actuarial Assumptions
Discount rate (2)	3.25		%	3.25		%	3.25		%	4.35		%	4.35		%	4.35		%
Expected return on plan assets (3)	3.95			4.05			3.35			4.60			4.70			4.15
Medical cost trend rate assumed for the next year - Pre-65	5.50			5.50			5.50			5.95			5.95			5.95
Medical/prescription drug cost trend rate assumed for the next year - Post-65	5.75			5.75			5.75			28.60			28.60			28.60
Prescription drug cost trend rate assumed for the next year - Pre-65	8.00			8.00			8.00			9.20			9.20			9.20
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	4.50			4.50			4.50			4.50			4.50			4.50
Year that the cost trend rates reach the ultimate trend rate - Pre-65	2028			2028			2028			2026			2026			2026
Year that the cost trend rates reach the ultimate trend rate - Post-65	2029			2029			2029			2027			2027			2027

(1)

Significant sources of gain for 2019 include favorable cost trend rates and benefit claims experience in addition to the change in mortality projection scale from MP2018 to MP2019. Significant sources of gain for 2018 include the increase in the discount rate from 3.60% to 4.35%, favorable benefit claims experience and cost trend rates in addition to the change in mortality projection scale from MP2017 to MP2018.


(2)	The discount rate assumption was determined by matching the projected cash flows of the plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.


(3)	The expected rate of return assumption was developed using the targeted asset allocation of the plans and the expected return for each asset class.

(d) Accumulated Other Comprehensive Income (Loss) (CenterPoint Energy and CERC)

CenterPoint Energy recognizes the funded status of its pension and other postretirement plans on its Consolidated Balance Sheets. To the extent this obligation exceeds amounts previously recognized in the Statements of Consolidated Income, CenterPoint Energy records a regulatory asset for that portion related to its rate regulated utilities. To the extent that excess liability does not relate to a rate regulated utility, the offset is recorded as a reduction to equity in accumulated other comprehensive income.

Amounts recognized in accumulated other comprehensive loss (gain) consist of the following:



	December 31,
	2019								2018
	Pension Benefits		Postretirement Benefits						Pension Benefits		Postretirement Benefits
	CenterPoint Energy		CenterPoint Energy			CERC			CenterPoint Energy		CenterPoint Energy			CERC
	(in millions)
Unrecognized actuarial loss (gain)	$	105	$	(16	)	$	(12	)	$	109	$	(7	)	$	(3	)
Unrecognized prior service cost	—		7			7			1		5			5
Deferred tax benefit	—		—			—			—		—			(9		)
Net amount recognized in accumulated other comprehensive loss (gain)	$	105	$	(9	)	$	(5	)	$	110	$	(2	)	$	(7	)

The changes in plan assets and benefit obligations recognized in other comprehensive income during 2019 are as follows:



	Pension Benefits			Postretirement Benefits
	CenterPoint Energy			CenterPoint Energy			CERC
	(in millions)
Net loss (gain)	$	4		$	(8	)	$	(6	)
Amortization of net loss	(8		)	—			—
Amortization of prior service cost	(1		)	1			(1		)
Total recognized in comprehensive income	$	(5	)	$	(7	)	$	(7	)
Total expense recognized in net periodic costs and Other comprehensive income	$	87		$	1		$	(1	)

(e) Pension Plan Assets (CenterPoint Energy)

In managing the investments associated with the benefit plans, CenterPoint Energy’s objective is to achieve and maintain a fully funded plan. This objective is expected to be achieved through an investment strategy that manages liquidity requirements while maintaining a long-term horizon in making investment decisions and efficient and effective management of plan assets.

As part of the investment strategy discussed above, CenterPoint Energy maintained the following weighted average allocation targets for its pension plans as of December 31, 2019:



	Minimum		Maximum
U.S. equity	19	%	29	%
International equity	8	%	18	%
Real estate	3	%	9	%
Fixed income	52	%	62	%
Cash	0	%	2	%

The following tables set forth by level, within the fair value hierarchy (see Note 10), CenterPoint Energy’s pension plan assets at fair value as of December 31, 2019 and 2018:



	Fair Value Measurements as of December 31,
	2019										2018
	(Level 1)			(Level 2)		(Level 3)		Total			(Level 1)			(Level 2)		(Level 3)		Total
	(in millions)
Cash	$	(7	)	$	—	$	—	$	(7	)	$	19		$	—	$	—	$	19
Corporate bonds:
Investment grade or above	—			699		—		699			—			368		—		368
Equity securities:
U.S. companies	69			—		—		69			60			—		—		60
Cash received as collateral from securities lending	61			—		—		61			77			—		—		77
U.S. treasuries	232			—		—		232			196			—		—		196
Mortgage backed securities	—			8		—		8			—			6		—		6
Asset backed securities	—			3		—		3			—			1		—		1
Municipal bonds	—			44		—		44			—			27		—		27
Mutual funds (2)	270			—		—		270			167			—		—		167
International government bonds	—			21		—		21			—			16		—		16
Obligation to return cash received as collateral from securities lending	(61		)	—		—		(61		)	(77		)	—		—		(77		)
Total investments at fair value	$	564		$	775	$	—	$	1,339		$	442		$	418	$	—	$	860
Investments measured by net asset value per share or its equivalent (1) (2)								666										656
Total Investments								$	2,005									$	1,516


(1)	Represents investments in common collective trust funds.


(2)	The amounts invested in mutual funds and common collective trust funds were allocated as follows:



	As of December 31,
	2019				2018
	Mutual Funds		Common Collective Trust Funds		Mutual Funds		Common Collective Trust Funds
International equities (1)	31	%	29	%	85	%	41	%
U.S. equities	49	%	51	%	15	%	5	%
Real estate	1	%	6	%	—	%	—	%
Fixed income	19	%	14	%	—	%	54	%


(1)	The amounts invested in international equities for 2018 include allocations of 34% in mutual funds and 4% in common collective trust funds,which were previously reported as allocations in emerging market equities.

The pension plans utilized both exchange traded and over-the-counter financial instruments such as futures, interest rate options and swaps that were marked to market daily with the gains/losses settled in the cash accounts. The pension plans did not include any holdings of CenterPoint Energy Common Stock as of December 31, 2019 or 2018.

(f) Postretirement Plan Assets

In managing the investments associated with the postretirement plans, the Registrants’ objective is to achieve and maintain a fully funded plan. This objective is expected to be achieved through an investment strategy that manages liquidity requirements while maintaining a long-term horizon in making investment decisions and efficient and effective management of plan assets.

As part of the investment strategy discussed above, the Registrants maintained the following weighted average allocation targets for the postretirement plans as of December 31, 2019:



	CenterPoint Energy				Houston Electric				CERC
	Minimum		Maximum		Minimum		Maximum		Minimum		Maximum
U.S. equity	13	%	23	%	13	%	23	%	15	%	25	%
International equity	3	%	13	%	3	%	13	%	2	%	12	%
Fixed income	69	%	79	%	69	%	79	%	68	%	78	%
Cash	0	%	2	%	0	%	2	%	0	%	2	%

The following table presents mutual funds by level, within the fair value hierarchy, the Registrants’ postretirement plan assets at fair value as of December 31, 2019 and 2018:



	Fair Value Measurements as of December 31,
	2019								2018
	Mutual Funds
	(Level 1)		(Level 2)		(Level 3)		Total		(Level 1)		(Level 2)		(Level 3)		Total
	(in millions)
CenterPoint Energy	$	128	$	—	$	—	$	128	$	114	$	—	$	—	$	114
Houston Electric	101		—		—		101		89		—		—		89
CERC	27		—		—		27		25		—		—		25

The amounts invested in mutual funds were allocated as follows:



	As of December 31,
	2019						2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
Fixed income	71	%	71	%	69	%	74	%	74	%	73	%
U.S. equities	21	%	21	%	24	%	19	%	19	%	21	%
International equities	8	%	8	%	7	%	7	%	7	%	6	%

(g) Benefit Plan Contributions

The Registrants made the following contributions in 2019 and expect to make the following minimum contributions in 2020 to the indicated benefit plans below:



	Contributions in 2019						Expected Minimum Contributions in 2020
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Qualified pension plans	$	86	$	—	$	—	$	76	$	—	$	—
Non-qualified pension plans	23		—		—		7		—		—
Postretirement benefit plans	17		10		3		17		9		3

The following benefit payments are expected to be paid by the pension and postretirement benefit plans:



	Pension Benefits		Postretirement Benefits
	CenterPoint Energy		CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	180	$	18	$	8	$	5
2021	178		18		8		4
2022	180		19		9		5
2023	181		20		10		5
2024	177		21		10		6
2025-2029	824		112		54		30

(h) Savings Plan

CenterPoint Energy maintains the CenterPoint Energy Savings Plan, a tax-qualified employee savings plan that includes a cash or deferred arrangement under Section 401(k) of the Code, and an employee stock ownership plan under Section 4975(e)(7) of the Code. Under the plan, participating employees may make pre-tax or Roth contributions and, if eligible, after-tax contributions up to certain federally mandated limits. Participating Registrants provide matching contributions and, as of January 1, 2020, nonelective contributions, if eligible, up to certain limits. CenterPoint Energy, through the Merger, also acquired additional defined contribution retirement savings plans sponsored by Vectren and its subsidiaries that are qualified under sections 401(a) and 401(k) of the Code, one of which merged into the CenterPoint Energy Savings Plan as of January 1, 2020.

The CenterPoint Energy Savings Plan has significant holdings of Common Stock. As of December 31, 2019, 11,051,800 shares of Common Stock were held by the savings plan, which represented approximately 13% of its investments. Given the concentration of the investments in Common Stock, the savings plan and its participants have market risk related to this investment. The savings plan limits the percentage of future contributions that can be invested in Common Stock to 25% and prohibits transfers of account balances where the transfer would result in more than 25% of a participant’s total account balance invested in Common Stock.

CenterPoint Energy allocates the savings plan benefit expense to Houston Electric and CERC related to their respective employees. The following table summarizes the Registrants’ savings plan benefit expense for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Savings plan benefit expenses (1)	$	58	$	18	$	18	$	43	$	17	$	18	$	41	$	17	$	17


(1)	Amounts presented in the table above are included in Operation and maintenance expense in the Registrants’ respective Statements of Consolidated Income and shown prior to any amounts capitalized.

(i) Other Benefits Plans

The Registrants participate in CenterPoint Energy’s plans that provide postemployment benefits for certain former or inactive employees, their beneficiaries and covered dependents, after employment but before retirement (primarily healthcare and life insurance benefits for participants in the long-term disability plan).

CenterPoint Energy maintains non-qualified deferred compensation plans, including plans acquired in the Merger, that provide benefits payable to eligible directors, officers and select employees or their designated beneficiaries at specified future dates or upon termination, retirement or death. Benefit payments are made from the general assets of the participating Registrants.

Expenses related to other benefit plans were recorded as follows:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Postemployment benefits	$	2	$	1	$	1	$	3	$	4	$	1	$	6	$	1	$	4
Deferred compensation plans	4		1		—		3		1		—		3		1		—

Amounts related to other benefit plans were included in Benefit Obligations in the Registrants’ accompanying Consolidated Balance Sheets as follows:



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Postemployment benefits	$	11	$	3	$	7	$	11	$	3	$	7
Deferred compensation plans	41		8		3		42		9		3
Split-dollar life insurance arrangements	32		1		—		36		1		—

(j) Change in Control Agreements and Other Employee Matters

CenterPoint Energy has a change in control plan, which was amended and restated on May 1, 2017. The plan generally provides, to the extent applicable, in the case of a change in control of CenterPoint Energy and covered termination of employment, for severance benefits of up to three times annual base salary plus bonus, and other benefits. Certain CenterPoint Energy officers, including the Executive Chairman, are participants under the plan.

Certain key employees of Vectren and its subsidiaries have change in control agreements or employment agreements that provide payments and other benefits upon a covered termination of employment.

As of December 31, 2019, the Registrants’ employees were covered by collective bargaining agreements as follows:



		Percentage of Employees Covered
	Agreement Expiration	CenterPoint Energy		Houston Electric		CERC
IBEW Local 66	May 2020	10	%	51	%	—
OPEIU Local 12 and Mankato	March and May 2021	2	%	—		3	%
Gas Workers Union Local 340	April 2020	3	%	—		12	%
IBEW Locals 949 & 1393 and USW Locals 12213 & 7441	December 2020	4	%	—		7	%
USW Locals 13-227 & 13-1 and IBEW Local 702	June and July 2022	5	%	—		12	%
Teamsters Local 135	September 2021	—		—		—
UWUA Local 175	October 2021	1	%	—		—
Trade Agreements of Infrastructure Services through the DCA and PLCA (1)	Various expiration dates in 2020–2022	27	%	—		—
Total		52	%	51	%	34	%

(1)

Infrastructure Services negotiates various trade agreements through contractor associations. The two primary associations are the DCA and the PLCA. These trade agreements are with a variety of construction unions including Laborer’s International Union of North America, International Union of Operating Engineers, United Association of Journeymen and Apprentices of the Plumbing and Pipe Fitting Industry, and Teamsters. The trade agreements have varying expiration dates in 2020, 2021 and 2022. In addition, these subsidiaries have various project agreements and small local agreements. These agreements expire upon completion of a specific project or on various dates throughout the year.

Income Taxes (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

$ 48

$ 89

$ 32

(25)

(806)

(5)

(770)

138

146

(729)

$ 929

$ 514

$ 1,063

21.00%

35.00%

Increase (decrease) in tax expense resulting from:

$ 195

$ 108

$ 372

State income tax expense, net of federal income tax

State valuation allowance, net of federal income tax

(4)

^[1]

^[2]

State law change, net of federal income tax

(21)

^[1]

^[2]

(1,113)

^[3]

(55)

^[1]

(24)

^[2]

(13)

(3)

(17)

(57)

(1,101)

$ 138

$ 146

$ (729)

15.00%

28.00%

(69.00%)

Benefits and compensation

$ 152

$ 160

Loss and credit carryforwards

447

356

111

Asset retirement obligations

Deferred Tax Assets, Derivative Instruments

Total deferred tax assets

Valuation allowance

(25)

(18)

848

673

Property, plant, and equipment

2,656

1,894

Investment in unconsolidated affiliates

1,010

987

Investment in marketable securities and indexed debt

344

395

586

478

Indexed debt securities derivative

Total deferred tax liabilities

180

131

4,776

3,912

Net deferred tax liabilities

3,928

3,239

Reconciliation of Unrecognized Tax Benefits, excluding interest and penalties:

Balance, beginning of year

Unrecognized tax benefits assumed through the Merger

(1)

Balance, end of year

State and Local Jurisdiction [Member]

Increase (decrease) in tax expense resulting from:

(21)

699

109

$ 70

104

127

(24)

(38)

(98)

(24)

(38)

(98)

(9)

$ 436

$ 425

$ 424

21.00%

35.00%

Increase (decrease) in tax expense resulting from:

$ 92

$ 89

$ 148

State income tax expense, net of federal income tax

(158)

^[4]

(21)

^[5]

(9)

^[6]

(7)

(5)

(11)

(12)

(157)

$ 80

$ 89

$ (9)

18.00%

21.00%

(2.00%)

Benefits and compensation

$ 14

$ 17

Asset retirement obligations

195

205

Total deferred tax assets

225

241

Property, plant, and equipment

1,129

1,087

Total deferred tax liabilities

126

177

1,255

1,264

Net deferred tax liabilities

1,030

1,023

$ (224)

(265)

Increase (decrease) in tax expense resulting from:

226

319

State valuation allowance, net of federal income tax

(18)

$ (265)

CERC Corp [Member] | State and Local Jurisdiction [Member]

618

Increase (decrease) in tax expense resulting from:

(4)

Valuation allowance

(15)

691

Federal Income Tax Rate Prior To TCJA [Member]

Federal Income Tax Rate Prior To TCJA [Member] | Houston Electric [Member]

35.00%

Federal Income Tax Rate Prior To TCJA [Member] | CERC Corp [Member]

35.00%

Federal Income Tax Rate After TCJA [Member]

35.00%

Federal Income Tax Rate After TCJA [Member] | Houston Electric [Member]

21.00%

Federal Income Tax Rate After TCJA [Member] | CERC Corp [Member]

21.00%

Continuing Operations [Member] | CERC Corp [Member]

21.00%

(9)

$ (31)

(10)

(9)

(41)

(249)

(32)

(224)

(265)

$ 226

$ 92

$ 319

21.00%

35.00%

Increase (decrease) in tax expense resulting from:

$ 47

$ 19

$ 112

State income tax expense, net of federal income tax

(12)

State law change, net of federal income tax

(4)

^[7]

(396)

^[8]

(18)

^[7]

(15)

^[9]

(3)

(1)

(33)

(377)

$ 14

$ 22

$ (265)

6.00%

24.00%

(83.00%)

Benefits and compensation

$ 24

$ 27

Loss and credit carryforwards

144

150

183

259

Asset retirement obligations

Total deferred tax assets

Valuation allowance

(15)

(18)

439

492

Property, plant, and equipment

821

773

Total deferred tax liabilities

909

898

Net deferred tax liabilities

470

406

Discontinued Operations [Member] | CERC Corp [Member]

$ 31

104

$ 0

$ 184

$ 265

0.00%

21.00%

35.00%

Increase (decrease) in tax expense resulting from:

$ 0

$ 39

$ 93

State income tax expense, net of federal income tax

$ 0

$ 46

$ 104

State Valuation Allowance, net of Federal Income Taxes [Member] | Continuing Operations [Member] | CERC Corp [Member]

0.00%

25.00%

39.00%

Increase (decrease) in tax expense resulting from:

State valuation allowance, net of federal income tax

$ (4)

^[7]

$ 11

^[9]

$ 3

Tax Basis Balance Sheet Adjustment [Member] | Continuing Operations [Member] | CERC Corp [Member]

Increase (decrease) in tax expense resulting from:

State valuation allowance, net of federal income tax

$ 0

$ 11

Charitable Contribution [Member]

Reconciliation of Unrecognized Tax Benefits, excluding interest and penalties:

177

Unrecognized tax benefits assumed through the Merger

Unrecognized Tax benefit, impacting ETR if recognized

Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations

Unrecognized Tax Benefit, including penalties and interest

Vectren [Member] | Charitable Contribution [Member]

Stockholders' Equity Note [Abstract]

$ 60

[1]	Recognized a $55 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions, a $21 million net benefit for the impact of state law changes that resulted in the remeasurement of state deferred taxes in those jurisdictions, and $4 million net benefit for the reduction in valuation allowances on certain state net operating losses that are now expected to be realized.
[2]	Recognized a $32 million deferred tax expense due to state law changes that resulted in remeasurement of state deferred taxes in those jurisdictions. Also recorded an additional $11 million valuation allowance on certain state net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. These items are partially offset by $24 million of amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions beginning in 2018.
[3]	Recognized a $1.1 billion deferred tax benefit from the remeasurement of CenterPoint Energy’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.
[4]	Recognized a $158 million deferred tax benefit from the remeasurement of Houston Electric’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.
[5]	Recognized $21 million of amortization of the net regulatory EDIT liability as decreed by regulators.
[6]	Recognized $9 million of amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions beginning in 2018.
[7]	Recognized $18 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions, $4 million net benefit for the impact of state law changes that resulted in the remeasurement of state deferred taxes in those jurisdictions and $4 million net benefit for the reduction in valuation allowances on certain state net operating losses that are now expected to be realized.
[8]	Recognized a $396 million deferred tax benefit from the remeasurement of CERC’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%. ASC 740 requires tax impacts of changes in tax laws or rates be reported in continuing operations. Therefore, CERC’s federal income tax benefit generated by the remeasurement of the ADFIT liability for Enable during 2017 and state law changes during 2016 associated with its investment in Enable are reported in continuing operations on CERC’s Statements of Consolidated Income. The ADFIT liability associated with CERC’s investment in Enable is reported as discontinued operations on CERC’s Consolidated Balance Sheets.
[9]	Recorded an additional $11 million valuation allowance on certain state net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. This item is partially offset by $15 million of amortization of the net regulatory EDIT liability in certain jurisdictions as decreed by regulators beginning in 2018.

Equity (CenterPoint Energy) (Tables)

12 Months Ended

Dec. 31, 2019

Dividends Declared [Table Text Block]

CenterPoint Energy declared dividends on its Common Stock during 2019, 2018 and 2017 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
October 17, 2019	November 21, 2019	December 12, 2019	$	0.2875	$	144
July 31, 2019	August 15, 2019	September 12, 2019	0.2875		145
April 25, 2019	May 16, 2019	June 13, 2019	0.2875		144
Total 2019			$	0.8625	$	433

December 12, 2018	February 21, 2019	March 14, 2019	$	0.2875	$	144
October 23, 2018	November 15, 2018	December 13, 2018	0.2775		139
July 26, 2018	August 16, 2018	September 13, 2018	0.2775		120
April 26, 2018	May 17, 2018	June 14, 2018	0.2775		120
Total 2018			$	1.1200	$	523



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
December 13, 2017	February 15, 2018	March 8, 2018	$	0.2775	$	120
October 25, 2017	November 16, 2017	December 8, 2017	0.2675		116
July 27, 2017	August 16, 2017	September 8, 2017	0.2675		115
April 27, 2017	May 16, 2017	June 9, 2017	0.2675		115
January 5, 2017	February 16, 2017	March 10, 2017	0.2675		115
Total 2017			$	1.3475	$	581

CenterPoint Energy declared dividends on its Series A Preferred Stock during 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
July 31, 2019	August 15, 2019	September 3, 2019	$	30.6250	$	24
Total 2019			$	30.6250	$	24

December 12, 2018	February 15, 2019	March 1, 2019	$	32.1563	$	26
Total 2018			$	32.1563	$	26

CenterPoint Energy declared dividends on its Series B Preferred Stock during 2019 and 2018 as presented in the table below:



Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)
October 17, 2019	November 15, 2019	December 2, 2019	$	17.5000	$	17
July 31, 2019	August 15, 2019	September 3, 2019	17.5000		17
April 25, 2019	May 15, 2019	June 3, 2019	17.5000		17
Total 2019			$	52.5000	$	51

December 12, 2018	February 15, 2019	March 1, 2019	$	17.5000	$	17
October 23, 2018	November 15, 2018	December 1, 2018	11.6667		11
Total 2018			$	29.1667	$	28

There were no Series A Preferred Stock or Series B Preferred Stock outstanding or dividends declared in 2017.

Dividend Requirement on Preferred Stock



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Series A Preferred Stock	$	49	$	18	$	—
Series B Preferred Stock	68		17		—
Total preferred stock dividend requirement	$	117	$	35	$	—

Convertible Debt [Table Text Block]

The following table illustrates the conversion rate per share of the Series B Preferred Stock, subject to certain anti-dilution adjustments:



Applicable Market Value of the Common Stock		Conversion Rate per Share of Series B Preferred Stock
Greater than $32.6990 (threshold appreciation price)		30.5820 shares of Common Stock
Equal to or less than $32.6990 but greater than or equal to $27.2494		Between 30.5820 and 36.6980 shares of Common Stock, determined by dividing $1,000 by the applicable market value
Less than $27.2494 (initial price)		36.6980 shares of Common Stock

The following table illustrates the conversion rate per depositary share, subject to certain anti-dilution adjustments:



Applicable Market Value of the Common Stock		Conversion Rate per Depository Share
Greater than $32.6990 (threshold appreciation price)		1.5291 shares of Common Stock
Equal to or less than $32.6990 but greater than or equal to $27.2494		Between 1.5291 and 1.8349 shares of Common Stock, determined by dividing $50 by the applicable market value
Less than $27.2494 (initial price)		1.8349 shares of Common Stock

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

Amounts recognized in accumulated other comprehensive loss (gain) consist of the following:



	December 31,
	2019								2018
	Pension Benefits		Postretirement Benefits						Pension Benefits		Postretirement Benefits
	CenterPoint Energy		CenterPoint Energy			CERC			CenterPoint Energy		CenterPoint Energy			CERC
	(in millions)
Unrecognized actuarial loss (gain)	$	105	$	(16	)	$	(12	)	$	109	$	(7	)	$	(3	)
Unrecognized prior service cost	—		7			7			1		5			5
Deferred tax benefit	—		—			—			—		—			(9		)
Net amount recognized in accumulated other comprehensive loss (gain)	$	105	$	(9	)	$	(5	)	$	110	$	(2	)	$	(7	)

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



	Year Ended December 31,
	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:
Remeasurement of pension and other postretirement plans	7			—			7			(19		)	—			1
Deferred loss from interest rate derivatives (1)	(3		)	(1		)	—			(19		)	(18		)	(1		)
Reclassified to earnings	1			—			—			—			—			—
Other comprehensive loss from unconsolidated affiliates	(1		)	—			—			—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—			1			—			1
Actuarial losses (2)	8			—			—			6			—			—
Tax benefit (expense)	(3		)	—			(2		)	6			4			(1		)
Net current period other comprehensive income (loss)	10			(1		)	5			(25		)	(14		)	—
Adoption of ASU 2018-02	—			—			—			(15		)	—			(1		)
Ending Balance	$	(98	)	$	(15	)	$	10		$	(108	)	$	(14	)	$	5

(1)

(2)

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

Unaudited Quarterly Information (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Income (loss) available to common shareholders

$ 3,230

$ 2,742

$ 2,798

$ 3,531

$ 3,036

$ 2,212

$ 2,186

$ 3,155

$ 12,301

$ 10,589

$ 9,614

Operating income (loss)

302

392

287

245

167

226

187

251

1,226

831

1,136

$ 128

$ 241

$ 165

$ 140

$ 90

$ 153

$ (75)

$ 165

$ 674

^[1]

$ 333

^[1]

$ 1,792

^[1]

Basic earnings per common share (1)

$ 0.25

^[2]

$ 0.48

^[2]

$ 0.33

^[2]

$ 0.28

^[2]

$ 0.18

^[2]

$ 0.35

^[2]

$ (0.17)

^[2]

$ 0.38

^[2]

$ 1.34

$ 0.74

$ 4.16

Diluted earnings per common share (1)

$ 0.25

^[2]

$ 0.47

^[2]

$ 0.33

^[2]

$ 0.28

^[2]

$ 0.18

^[2]

$ 0.35

^[2]

$ (0.17)

^[2]

$ 0.38

^[2]

$ 1.33

$ 0.74

$ 4.13

$ 791

$ 368

$ 1,792

$ 680

$ 859

$ 765

$ 686

$ 728

$ 897

$ 854

$ 755

2,990

3,234

2,998

Operating income (loss)

269

169

227

181

119

618

625

637

185

100

143

101

356

336

433

Income (loss) from continuing operations

1,734

1,126

1,342

2,368

2,303

^[3]

1,312

^[3]

1,328

^[3]

2,400

^[3]

6,570

7,343

6,603

Operating income (loss)

196

^[3]

(7)

^[3]

131

^[3]

350

222

467

^[3]

(35)

^[3]

(8)

^[3]

212

584

Income (loss) from discontinued operations, net of tax

(2)

^[3]

138

161

Property, Plant and Equipment [Abstract]

$ 53

$ (7)

$ 28

$ 138

$ 33

^[3]

$ 9

^[3]

$ 36

^[3]

$ 130

^[3]

$ 212

$ 208

$ 745

[1]	Income available to common shareholders for the year ended December 31, 2019 includes net income from businesses acquired in the Merger of $190 million. See Note 4. Income available to common shareholders for the year ended December 31, 2017 includes a reduction in income tax expense of $1,113 million due to tax reform. See Note 15 for further discussion of the impacts of the TCJA.
[2]	Quarterly earnings (loss) per common share are based on the weighted average number of shares outstanding during the quarter, and the sum of the quarters may not equal annual earnings (loss) per common share.
[3]	Amounts have been recast to reflect discontinued operations in all periods presented.

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2019

Property, Plant and Equipment [Text Block]

Property, Plant and Equipment

(a) Property, Plant and Equipment

Property, plant and equipment includes the following:



		December 31, 2019						December 31, 2018
	Weighted Average Useful Lives	Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net		Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net
	(in years)	(in millions)
CenterPoint Energy
Electric Transmission & Distribution	37	$	14,360	$	4,634	$	9,726	$	12,148	$	3,746	$	8,402
Electric Generation (1)	27	1,780		698		1,082		—		—		—
Natural Gas Distribution	29	12,695		3,731		8,964		7,257		2,128		5,129
Energy Services (2)	27	136		53		83		121		43		78
Infrastructure Services (3)	10	317		22		295		—		—		—
Other property	19	1,397		602		795		741		306		435
Total		$	30,685	$	9,740	$	20,945	$	20,267	$	6,223	$	14,044
Houston Electric
Electric Transmission	46	$	3,358	$	674	$	2,684	$	3,077	$	650	$	2,427
Electric Distribution	35	7,876		2,586		5,290		7,524		2,553		4,971
Other transmission & distribution property	19	1,595		537		1,058		1,547		543		1,004
Total		$	12,829	$	3,797	$	9,032	$	12,148	$	3,746	$	8,402



		December 31, 2019						December 31, 2018
	Weighted Average Useful Lives	Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net		Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net
	(in years)	(in millions)
CERC
Natural Gas Distribution	29	$	7,933	$	2,208	$	5,725	$	7,257	$	2,128	$	5,129
Energy Services (2)	27	136		53		83		121		43		78
Other property	16	55		27		28		53		34		19
Total		$	8,124	$	2,288	$	5,836	$	7,431	$	2,205	$	5,226

(1)

SIGECO and AGC own a 300 MW unit at the Warrick Power Plant (Warrick Unit 4) as tenants in common. SIGECO’s share of the cost of this unit as of December 31, 2019, is $194 million with accumulated depreciation totaling $137 million. AGC and SIGECO share equally in the cost of operation and output of the unit. SIGECO’s share of operating costs is included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income.


(2)	On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.


(3)	On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Securities Purchase Agreement to sell the businesses within its Infrastructure Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

(b) Depreciation and Amortization

The following table presents depreciation and amortization expense for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Depreciation	$	920	$	339	$	281	$	626	$	342	$	264	$	619	$	354	$	243
Amortization of securitized regulatory assets	271		271		—		531		531		—		329		329		—
Other amortization	96		38		24		86		44		29		88		41		36
Total	$	1,287	$	648	$	305	$	1,243	$	917	$	293	$	1,036	$	724	$	279

The Registrants recorded AROs associated with the removal of asbestos and asbestos-containing material in its buildings, including substation building structures. CenterPoint Energy recorded AROs relating to the closure of the ash ponds at A.B. Brown and F.B. Culley. CenterPoint Energy and Houston Electric also recorded AROs relating to treated wood poles for electric distribution, distribution transformers containing PCB (also known as Polychlorinated Biphenyl), and underground fuel storage tanks. CenterPoint Energy and CERC also recorded AROs relating to gas pipelines abandoned in place. The estimates of future liabilities were developed using historical information, and where available, quoted prices from outside contractors.

A reconciliation of the changes in the ARO liability recorded in Other non-current liabilities on each of the Registrants’ respective Consolidated Balance Sheets is as follows:



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning balance	$	258	$	34	$	221	$	281		$	35		$	243
Addition from Merger with Vectren	116		—		—		—			—			—
Accretion expense (1)	16		1		10		10			1			9
Revisions in estimates (2)	149		7		94		(33		)	(2		)	(31		)
Ending balance	$	539	$	42	$	325	$	258		$	34		$	221


(1)	Reflected in Regulatory assets on each of the Registrants’ respective Consolidated Balance Sheets.

(2)

In 2019, the Registrants reflected an increase in their respective ARO liability, which is primarily attributable to decreases in the long-term interest rates used for discounting in the ARO calculation and increased estimated closure costs for CenterPoint Energy’s electric generation. In 2018, CenterPoint Energy and CERC reflected a decrease in their respective ARO liability, which is primarily attributable to increases in the long-term interest rates used for discounting in the ARO calculation.

Reportable Segments Financial Data (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

$ 3,230

$ 2,742

$ 2,798

$ 3,531

$ 3,036

$ 2,212

$ 2,186

$ 3,155

$ 12,301

$ 10,589

$ 9,614

1,287

1,243

1,036

302

392

287

245

167

226

187

251

1,226

831

1,136

35,439

27,009

35,439

27,009

22,736

Capital expenditures per Statements of Consolidated Cash Flows

2,587

1,720

1,494

2,506

1,651

1,426

Midstream Investments’ equity earnings, net

162

230

307

265

2,129

2,044

2,129

2,044

Midstream Investments’ equity earnings, net

^[1],[2]

229

307

265

Electric Transmission & Distribution [Member]

^[3]

2,996

3,232

2,997

648

917

724

624

623

636

Electric Transmission & Distribution [Member] | Affiliates of NRG Energy, Inc. [Member]

1,033

952

924

Electric Transmission & Distribution [Member] | Affiliates of Vistra Energy Corp. [Member]

727

705

713

Indiana Electric Integrated [Member]

263

251

229

^[3]

523

183

3,643

2,931

2,606

417

277

260

408

266

348

1,098

638

523

3,653

4,411

3,997

(47)

126

^[4]

1,186

Midstream Investments [Member]

^[5]

^[5]

^[5]

Midstream Investments [Member] | Enable Midstream Partners [Member]

^[5]

Midstream Investments’ equity earnings, net

229

307

265

Corporate and Other [Member]

300

(23)

(11)

Operating Segments [Member] | Electric Transmission & Distribution [Member]

194

110

Operating Segments [Member] | Indiana Electric Integrated [Member]

11,264

10,509

11,264

10,509

10,292

Operating Segments [Member] | Natural Gas Distribution [Member]

3,168

Operating Segments [Member] | Energy Services [Member]

13,903

6,956

13,903

6,956

6,608

Operating Segments [Member] | Infrastructure Services [Member]

1,301

1,558

1,301

1,558

1,521

Operating Segments [Member] | Midstream Investments [Member]

1,077

Operating Segments [Member] | Corporate and Other [Member]

^[5]

2,473

2,482

2,473

2,482

2,472

Intersegment Eliminations [Member]

^[6]

4,784

6,156

4,784

6,156

2,497

(173)

(146)

(85)

Intersegment Eliminations [Member] | Electric Transmission & Distribution [Member]

(2,531)

(652)

(2,531)

(652)

(654)

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

Intersegment Eliminations [Member] | Energy Services [Member]

(40)

(36)

(33)

Intersegment Eliminations [Member] | Infrastructure Services [Member]

(129)

(110)

(52)

Intersegment Eliminations [Member] | Midstream Investments [Member]

(4)

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

^[5]

Segment Reconciling Items [Member]

(81)

(69)

(68)

680

859

765

686

728

897

854

755

2,990

3,234

2,998

648

917

724

269

169

227

181

119

618

625

637

Capital expenditures per Statements of Consolidated Cash Flows

11,262

10,507

11,262

10,507

1,025

922

875

Houston Electric [Member] | Electric Transmission & Distribution [Member] | Affiliates of NRG Energy, Inc. [Member]

915

1,124

915

1,124

Houston Electric [Member] | Electric Transmission & Distribution [Member] | Affiliates of Vistra Energy Corp. [Member]

727

705

713

263

251

229

1,734

1,126

1,342

2,368

2,303

^[7]

1,312

^[7]

1,328

^[7]

2,400

^[7]

6,570

7,343

6,603

305

293

279

$ 23

$ 58

$ 196

^[7]

$ (7)

^[7]

$ 22

^[7]

$ 131

^[7]

350

222

467

^[8]

8,439

8,214

8,439

8,214

10,112

Capital expenditures per Statements of Consolidated Cash Flows

785

658

534

776

633

513

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

203

258

203

258

2,911

2,931

2,606

289

277

260

316

266

348

773

638

523

3,654

4,411

3,997

(47)

126

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

(7)

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

CERC Corp [Member] | Operating Segments [Member] | Energy Services [Member]

^[8]

7,497

6,956

7,497

6,956

6,608

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

^[8]

1,301

1,558

1,301

1,558

1,521

CERC Corp [Member] | Intersegment Eliminations [Member]

^[8]

149

(168)

(146)

(85)

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

^[8]

(508)

(366)

(508)

(366)

(559)

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

(40)

(36)

(33)

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

(128)

(110)

(52)

CERC Corp [Member] | Segment Reconciling Items [Member]

Pension and Other Postretirement Plans Costs [Member] | Corporate and Other [Member]

(9)

(25)

(21)

Cash and Cash Equivalents [Member]

584

$ 665

584

$ 665

600

Discontinued Operations, Disposed of by Means Other than Sale, Spinoff [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]

Short-term Investments

$ 3,900

3,900

Investment in unconsolidated affiliates - discontinued operations

^[8]

2,472

$ 0

$ 162

[1]

Equity earnings for the year ended December 31, 2019 includes CenterPoint Energy’s share of Enable’s $86 million goodwill impairment recorded in the fourth quarter of 2019.

[2]

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

[3]

CenterPoint Energy’s Houston Electric T&D’s revenues from major customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229

[4]

Includes revenues not eliminated in consolidation for pipeline construction and repair services of $162 million capitalized by CenterPoint Energy’s NGD for the 11 months ended December 31, 2019. See Note 2(b).

[5]

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



	Year Ended December 31,
	2019		2018		2016
	(in millions)
Enable	$	229	$	307	$	265

[6]

Total assets included pension and other postemployment-related regulatory assets of $584 million, $665 million and $600 million as of December 31, 2019, 2018 and 2017, respectively. 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.

[7]

Amounts have been recast to reflect discontinued operations in all periods presented.

[8]

On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 11.

Short Term Borrowings and Long Term Debt Schedule of Debt (Details)
$ in Millions

12 Months Ended

Dec. 31, 2019

USD ($)

day

Dec. 31, 2018

USD ($)

Unamortized Issuance Costs

$ (22)

$ (13)

Unamortized Discount (Premium), Net

(7)

(2)

Long-term Debt

14,244

8,682

Debt, Current

^[1]

868

482

Interest Expense, Related Party

Commercial paper issued in connection with the Merger

$ 764

Number of days until commercial paper maturity | day

ZENS due 2029 (2)

^[2]

$ 0

^[1],[2]

$ 19

Senior notes 2.50% to 7.08% due 2020 to 2049 (3)

2.00%

$ 3,728

^[3]

2,000

Variable rate term loan [Member]

^[1]

100

^[3]

1,000

^[1]

$ 500

First Mortgage Bonds [Member]

2.275%

^[4]

$ 293

Pollution control bonds 5.125% due 2028 (5)

^[1],[4]

^[5]

^[1],[5]

^[6]

1,901

^[7]

Other Debt Obligations [Member]

^[1],[6],[7]

Parent Company [Member] | Senior notes 2.50% to 7.08% due 2020 to 2049 (3) | Minimum [Member]

^[1]

$ 18

Parent Company [Member] | Senior notes 2.50% to 7.08% due 2020 to 2049 (3) | Maximum [Member]

2.50%

Parent Company [Member] | Variable rate term loan [Member] | Minimum [Member]

7.08%

Parent Company [Member] | Variable rate term loan [Member] | Maximum [Member]

2.275%

Parent Company [Member] | First Mortgage Bonds [Member] | Minimum [Member]

2.56%

Parent Company [Member] | First Mortgage Bonds [Member] | Maximum [Member]

2.19%

Parent Company [Member] | Pollution control bonds 5.125% due 2028 (5)

6.72%

$ 68

Amount of debt secured by general mortgage bonds

5.125%

$ 68

VUHI [Member]

Notes Payable, Related Parties, Noncurrent

$ 568

Number of days until commercial paper maturity | day

VUHI [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047

$ 532

Unamortized Issuance Costs

(27)

(24)

Unamortized Discount (Premium), Net

(15)

(11)

Long-term Debt

4,719

4,258

Debt, Current

^[1]

231

458

Houston Electric [Member] | First mortgage bonds 9.15% due 2021

102

^[1]

$ 0

Amount of debt secured by general mortgage bonds

9.15%

$ 102

Houston Electric [Member] | General mortgage bonds 1.85% to 6.95% due 2021 to 2048

3,912

3,212

Amount of debt secured by general mortgage bonds

^[1]

$ 4,000

Houston Electric [Member] | General mortgage bonds 1.85% to 6.95% due 2021 to 2048 | Minimum [Member]

Houston Electric [Member] | General mortgage bonds 1.85% to 6.95% due 2021 to 2048 | Maximum [Member]

1.85%

Houston Electric [Member] | System restoration bonds 4.243% due 2022

6.95%

$ 134

197

^[1]

$ 62

Houston Electric [Member] | Transition bonds 5.302% due 2019

4.243%

$ 0

^[1]

$ 0

208

Houston Electric [Member] | Transition bonds 5.234% due 2020

5.302%

$ 0

^[1]

$ 29

Houston Electric [Member] | Transition bonds 2.161% to 3.028% due 2020 to 2024

5.234%

$ 613

753

Houston Electric [Member] | Transition bonds 2.161% to 3.028% due 2020 to 2024 | Minimum [Member]

^[1]

$ 140

135

Houston Electric [Member] | Transition bonds 2.161% to 3.028% due 2020 to 2024 | Maximum [Member]

2.161%

3.028%

Unamortized Issuance Costs

^[8]

$ (13)

(15)

Unamortized Discount (Premium), Net

^[8]

(11)

(17)

Long-term Debt

^[8]

2,546

2,371

Debt, Current

^[1],[8]

CERC Corp [Member] | Commercial paper (4)

^[6],[8]

377

210

CERC Corp [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047

^[1],[8]

^[8]

2,193

CERC Corp [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047 | Minimum [Member]

^[1],[8]

$ 0

CERC Corp [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047 | Maximum [Member]

3.55%

Indiana Gas [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047

6.625%

$ 96

VCC [Member]

Notes Payable, Related Parties, Noncurrent

$ 191

Vectren [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047 | Minimum [Member]

Vectren [Member] | Senior notes 3.55% to 6.625% due 2021 to 2047 | Maximum [Member]

3.72%

Equity Method Investments and Joint Ventures [Abstract]

7.08%

[1]	Includes amounts due or exchangeable within one year of the date noted.
[2]	CenterPoint Energy’s ZENS obligation is bifurcated into a debt component and an embedded derivative component. For additional information regarding ZENS, see Note 12(b). As ZENS are exchangeable for cash at any time at the option of the holders, these notes are classified as a current portion of long-term debt.
[3]	Includes $532 million of senior notes issued by VUHI and $96 million of senior notes issued by Indiana Gas. The senior notes have stated interest rates that range from 3.72% to 7.08%. The senior notes issued by VUHI are guaranteed by SIGECO, Indiana Gas and VEDO. 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 of senior notes 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.
[4]	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture.
[5]	$68 million and $68 million of these series of debt were secured by general mortgage bonds of Houston Electric as of December 31, 2019 and 2018, respectively. These general mortgage bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.
[6]	Classified as long-term debt because the termination date of the facility that backstops the commercial paper is more than one year from the date noted.
[7]	Commercial paper issued by VUHI has maturities up to 30 days.
[8]	Issued by CERC Corp.

Unconsolidated Affiliate (CenterPoint Energy and CERC)

12 Months Ended

Dec. 31, 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 December 31, 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):



	December 31, 2019		December 31, 2018
	(in millions)
Enable	$	2,406	$	2,482
Other (1)	2		—
Total	$	2,408	$	2,482


(1)	Represents the fair value of non-utility equity investments acquired in the Merger.

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 December 31, 2019, CenterPoint Energy’s investment in Enable is $10.29 per unit and Enable’s common unit price closed at $10.03 per unit (approximately $61 million below carrying value). Based on an analysis of its investment in Enable as of December 31, 2019, CenterPoint Energy believes that the decline in the value of its investment is temporary, and that the carrying value of its investment of $2.4 billion will be recovered.

Equity in Earnings of Unconsolidated Affiliates, net (CenterPoint Energy):



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Enable (1)	$	229	$	307	$	265
Other	1		—		—
Total	$	230	$	307	$	265


(1)	Equity earnings for the year ended December 31, 2019 includes CenterPoint Energy’s share of Enable’s $86 million goodwill impairment recorded in the fourth quarter of 2019.

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



	As of December 31,
	2019				2018
	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)
CenterPoint Energy (3)	53.7	%	233,856,623	14,520,000	54.0	%	233,856,623	14,520,000
OGE	25.5	%	110,982,805	—	25.6	%	110,982,805	—
Public unitholders	20.8	%	90,361,937	—	20.4	%	88,392,983	—
Total Units Outstanding	100.0	%	435,201,365	14,520,000	100.0	%	433,232,411	14,520,000


(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 Consolidated Balance Sheets, was $363 million as of both December 31, 2019 and 2018. No

impairment charges or adjustment to carrying value were made as no observable price changes were identified in the current or prior reporting periods.


(3)	Prior to the Internal Spin completed in September 2018, CenterPoint Energy’s investment in Enable’s common units, excluding the Enable Series A Preferred Units held directly by CenterPoint Energy, was held indirectly through CERC.

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):

CenterPoint Energy and OGE held the following interests in Enable GP as of both December 31, 2019 and 2018:



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


(1)	As of December 31, 2019, 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



	Year Ended December 31,
	2019				2018				2017
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	1.2970	$	303	$	1.2720	$	297	$	1.2720	$	297
Enable Series A Preferred Units	2.5000		36		2.5000		36		2.5000		36
Total CenterPoint Energy			$	339			$	333			$	333

CERC



	Year Ended December 31,
	2018				2017
	Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.9540	$	223	$	1.2720	$	297
Total CERC			223				297


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

Transactions with Enable (CenterPoint Energy and CERC):



	Year Ended December 31,
	2019		2018		2017
CenterPoint Energy	(in millions)
Natural gas expenses, including transportation and storage costs (1)	$	120	$	122	$	115
Reimbursement of support services (2)	—		4		4
CERC
Natural gas expenses, including transportation and storage costs (1)	120		122		115
Reimbursement of support services (2)	—		4		4


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


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



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

CERC’s continuing involvement with Enable subsequent to the Internal Spin is limited to its natural gas purchases from Enable.

Summarized consolidated income (loss) information for Enable is as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
Operating revenues	$	2,960		$	3,431		$	2,803
Cost of sales, excluding depreciation and amortization	1,279			1,819			1,381
Depreciation and amortization	433			398			366
Operating income	569			648			528
Goodwill impairment	86			—			—
Net income attributable to Enable common units	360			485			400
Reconciliation of Equity in Earnings (Losses), net:
CenterPoint Energy’s interest	$	193		$	262		$	216
Basis difference amortization (1)	47			47			49
Loss on dilution, net of proportional basis difference recognition	(11		)	(2		)	—
CenterPoint Energy’s equity in earnings, net	$	229		$	307		$	265


(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 consolidated balance sheet information for Enable is as follows:



	December 31,
	2019			2018
	(in millions)
Current assets	$	389		$	449
Non-current assets	11,877			11,995
Current liabilities	780			1,615
Non-current liabilities	4,077			3,211
Non-controlling interest	37			38
Preferred equity	362			362
Accumulated other comprehensive loss	(3		)	—
Enable partners’ equity	7,013			7,218
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,767		$	3,896
CenterPoint Energy’s basis difference	(1,361		)	(1,414		)
CenterPoint Energy’s equity method investment in Enable	$	2,406		$	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 in the equity investment of 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 Statements of Consolidated Income for the periods presented. CERC’s equity method investment and related deferred income tax liabilities have been classified as Investment in unconsolidated affiliate - discontinued operations and Deferred income taxes, net - discontinued operations, respectively, in CERC’s Consolidated Balance Sheets for the periods presented. The following table presents amounts included in Income from discontinued operations, net of tax in CERC’s Statements of Consolidated Income.



	Year Ended December 31,
	2018		2017
	(in millions)
Equity in earnings of unconsolidated affiliate, net	$	184	$	265
Income tax expense	46		104
Income from discontinued operations, net of tax	$	138	$	161

Related Party Transactions (Houston Electric and CERC) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Capital distribution to parent associated with the Internal Spin (1)

$ 0

Cash dividends paid to parent

376

209

180

Capital distribution to parent associated with the Internal Spin (1)

Houston Electric [Member] | Other, net [Member]

Interest income (expense), net (1)

^[1]

Houston Electric [Member] | Operation And Maintenance Expense [Member]

Net affiliate service charges (billings)

(8)

(17)

(9)

Houston Electric [Member] | Operation And Maintenance Expense [Member] | CenterPoint Energy [Member]

Corporate service charges

177

190

188

Houston Electric [Member] | Accounts and notes receivable (payable) - affiliate companies [Member]

Money pool investments (borrowings) (1)

^[2]

$ 481

Money Pool Borrowings

^[2]

$ (1)

Houston Electric [Member] | Investments [Member]

Weighted average interest rate

1.98%

2.42%

Cash dividends paid to parent

$ 120

$ 360

601

Capital distribution to parent associated with the Internal Spin (1)

^[3],[4]

1,473

^[4]

CERC Corp [Member] | Other, net [Member]

Interest income (expense), net (1)

^[1]

CERC Corp [Member] | Operation And Maintenance Expense [Member]

Net affiliate service charges (billings)

Pipeline construction and repair service charges

^[5]

CERC Corp [Member] | Operation And Maintenance Expense [Member] | CenterPoint Energy [Member]

Corporate service charges

141

147

128

CERC Corp [Member] | Non-utility revenue [Member]

Natural gas sales

^[6]

CERC Corp [Member] | Accounts and notes receivable (payable) - affiliate companies [Member]

Money pool investments (borrowings) (1)

^[2]

$ 0

$ 114

CERC Corp [Member] | Investments [Member]

Weighted average interest rate

1.98%

2.42%

Additional Paid-in Capital [Member] | Houston Electric [Member]

Additional Paid-in Capital [Member] | CERC Corp [Member]

$ 590

$ 200

Capital distribution to parent associated with the Internal Spin (1)

129

960

$ (28)

$ (1,473)

$ 0

[1]	Interest income is included in Other, net and interest expense is included in Interest and other finance charges on Houston Electric’s and CERC’s respective Statements of Consolidated Income.
[2]	Included in Accounts and notes receivable (payable)–affiliated companies in Houston Electric’s and CERC’s Consolidated Balance Sheets.
[3]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.
[4]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.
[5]	Represents charges from Infrastructure Services to CERC’s NGD for the period February 1, 2019 through December 31, 2019.
[6]	Represents sales to Indiana Electric from CES for the period February 1, 2019 through December 31, 2019.

Mergers and Acquisitions

12 Months Ended

Dec. 31, 2019

Business Combinations [Abstract]

Mergers and Acquisitions [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 Statements of Consolidated Income during the year ended December 31, 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 Statements of Consolidated Income during the year ended December 31, 2019. Total severance cost for the year ended December 31, 2019 was $102 million.

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 14 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 value of Vectren’s tangible and intangible assets and liabilities subject to these rate-setting

provisions approximate their carrying values on the Merger Date. 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 purchase price allocation as of December 31, 2019 (in millions):



Cash and cash equivalents	$	16
Other current assets	577
Property, plant and equipment, net	5,147
Identifiable intangibles	297
Regulatory assets	338
Other assets	141
Total assets acquired	6,516
Current liabilities	648
Regulatory liabilities	938
Other liabilities	886
Long-term debt	2,401
Total liabilities assumed	4,873
Net assets acquired	1,643
Goodwill	4,339
Total purchase price consideration	$	5,982

CenterPoint Energy completed a final valuation analysis necessary to determine the fair market values of all of Vectren’s assets and liabilities and the allocation of its purchase price. Changes from the preliminary purchase price allocation originally reported in the first quarter of 2019 primarily included additional information obtained related to intangible assets and the allocation of the fair value between reporting units.

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. The value assigned to goodwill will not be deductible for tax purposes.

The fair value of the identifiable intangible assets and related useful lives as included in the purchase price allocation as of December 31, 2019 include:



	Weighted Average Useful Lives	Estimated Fair Value
	(in years)	(in millions)
Operation and maintenance agreements	24	$	12
Customer relationships	18	200
Construction backlog	1	27
Trade names	10	58
Total		$	297

Amortization expense related to the operation and maintenance agreements and construction backlog was $24 million in 2019, and is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Statements of Consolidated Income.

Amortization expense related to customer relationships and trade names was $16 million in 2019 and is included in Depreciation and amortization expense on CenterPoint Energy’s Statements of Consolidated Income.

The results of operations for Vectren included in CenterPoint Energy’s Consolidated Financial Statements from the Merger Date for the year ended December 31, 2019 are as follows:



	(in millions)
Operating revenues	$	2,729
Net income	190

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.



	Year Ended December 31,
	2019			2018
	(in millions)
Operating revenues	$	12,547		$	13,282
Net income	812		(1)	458		(2)


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


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

CenterPoint Energy incurred integration costs in connection with the Merger of $83 million for the year ended December 31, 2019, which were included in Operation and maintenance expenses in CenterPoint Energy’s Statements of Consolidated Income.

Acquisition of Utility Pipeline Construction Company. An acquisition was made during the year ended December 31, 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 has been finalized. The results of operations for the acquired company have been included in CenterPoint Energy’s 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.

Fair Value Measurements (Details)
$ in Millions

12 Months Ended

Dec. 31, 2019

USD ($)

Dec. 31, 2018

USD ($)

Dec. 31, 2017

USD ($)

Assets

Total derivative assets, netting adjustment

$ 47

$ 57

^[1]

(98)

(82)

1,068

747

Total derivative liabilities, netting adjustment

^[1]

(161)

(101)

Fair value measurement using significant unobservable input (level 3) reconciliation [Roll Forward]

996

732

Transfers out of Level 3 (1)

^[2]

(622)

^[2]

$ (704)

Total gains

Total settlements

(22)

(39)

(11)

Transfers into Level 3

(1)

^[3]

(6)

656

(17)

Ending balance (2)

^[2]

(622)

The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date (3)

Carrying amount [Member]

^[4]

15,093

9,140

Fair value [Member]

^[4]

16,067

9,308

Natural gas [Member]

Derivative fair value offsets, net

Fair Value, Inputs, Level 1 [Member]

Assets

874

609

Fair Value, Inputs, Level 2 [Member]

Assets

250

173

Fair Value, Inputs, Level 3 [Member]

1,120

792

Assets

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

$ 24

Fair Value, assets and liabilities measured on recurring basis, financial statement captions

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

1.44

Fair Value, assets and liabilities measured on recurring basis, financial statement captions

Fair Value, Measurements, Recurring [Member]

5.20

Assets

$ 825

542

Fair Value, Measurements, Recurring [Member] | Natural gas [Member]

^[5]

Assets

Natural gas derivative netting adjustment

^[1],[6]

(98)

(82)

^[6]

194

138

Derivative liabilities, netting adjustment

^[1],[6]

(161)

(101)

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

^[6]

107

Derivative liabilities, netting adjustment

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

893

601

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

Assets

825

542

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

^[5]

Assets

^[6],[7]

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

^[6],[7]

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

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

Assets

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

^[5]

Assets

^[6]

250

173

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

^[6]

217

191

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

893

601

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

Assets

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

^[5]

Assets

^[6]

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

^[6]

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

Total derivative assets, netting adjustment

Assets

Total derivative liabilities, netting adjustment

Houston Electric [Member] | Carrying amount [Member]

Houston Electric [Member] | Fair value [Member]

^[4]

4,950

4,717

Houston Electric [Member] | Fair Value, Inputs, Level 1 [Member]

^[4]

5,457

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]

^[5]

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]

^[5]

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]

^[5]

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]

^[5]

Assets

Total derivative assets, netting adjustment

^[1]

(98)

(82)

207

152

Total derivative liabilities, netting adjustment

^[1]

(161)

(101)

Fair value measurement using significant unobservable input (level 3) reconciliation [Roll Forward]

107

Transfers out of Level 3 (1)

^[2]

Total gains

Total settlements

(22)

(39)

(11)

Transfers into Level 3

(1)

^[3]

(6)

(12)

(17)

Ending balance (2)

^[2]

The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date (3)

CERC Corp [Member] | Carrying amount [Member]

$ 0

CERC Corp [Member] | Fair value [Member]

2,546

2,371

CERC Corp [Member] | Natural gas [Member]

2,803

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

250

173

CERC Corp [Member] | Fair Value, Inputs, Level 3 [Member]

195

191

Assets

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

$ 24

Fair Value, assets and liabilities measured on recurring basis, financial statement captions

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

1.44

Fair Value, assets and liabilities measured on recurring basis, financial statement captions

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member]

5.20

Assets

$ 2

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Natural gas [Member]

^[5]

Assets

Natural gas derivative netting adjustment

^[1],[6]

(98)

(82)

^[6]

194

138

Derivative liabilities, netting adjustment

^[1],[6]

(161)

(101)

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

^[6]

107

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural gas [Member]

^[5]

Assets

^[6],[7]

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

^[6],[7]

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural gas [Member]

^[5]

Assets

^[6]

250

173

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

^[6]

195

191

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural gas [Member]

^[5]

Assets

^[6]

Natural gas inventory [Member] | Fair Value, Measurements, Recurring [Member]

^[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

Energy Services [Member] | CERC Corp [Member]

Financial Data for Business Segments [Table Text Block]

$ 48

[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:



	December 31, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	63	$	63	$	19	$	19

[2]

CenterPoint Energy and CERC did not have significant Level 3 purchases or sales during any of the years ended December 31, 2019, 2018 or 2017.

[3]

During 2018, CenterPoint Energy transferred its indexed debt securities derivative from Level 3 to Level 2 to reflect changes in the significance of the unobservable inputs used in the valuation.

[4]

Includes Securitization Bond debt.

[5]

Amounts are included in Prepaid and Other Current Assets and Other Assets in the Consolidated Balance Sheets.

[6]

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

[7]

Reportable Segments (Tables)

12 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Financial data for reportable segments and products and services are as follows:

CenterPoint Energy



	Revenues from External Customers			Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets				Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2019:
Houston Electric T&D	$	2,996	(1)	$	—		$	648	$	624		$	11,264			$	1,033
Indiana Electric Integrated	523			—			91		90			3,168				183
Natural Gas Distribution	3,643			40			417		408			13,903				1,098
Energy Services	3,653			129			16		32			1,301				12
Infrastructure Services	1,186		(2)	4			50		95			1,077				67
Midstream Investments (3)	—			—			—		—			2,473				—
Corporate and Other	300			—			65		(23		)	4,784			(4)	194
Eliminations	—			(173		)	—		—			(2,531		)		—
Consolidated	$	12,301		$	—		$	1,287	$	1,226		$	35,439			$	2,587
Reconciling items																(81		)
Capital expenditures per Statements of Consolidated Cash Flows																$	2,506

As of and for the year ended December 31, 2018:
Houston Electric T&D	$	3,232	(1)	$	—		$	917	$	623		$	10,509			$	952
Natural Gas Distribution	2,931			36			277		266			6,956				638
Energy Services	4,411			110			16		(47		)	1,558				20
Midstream Investments (3)	—			—			—		—			2,482				—
Corporate and Other	15			—			33		(11		)	6,156			(4)	110
Eliminations	—			(146		)	—		—			(652		)		—
Consolidated	$	10,589		$	—		$	1,243	$	831		$	27,009			$	1,720
Reconciling items																(69		)
Capital expenditures per Statements of Consolidated Cash Flows																$	1,651

As of and for the year ended December 31, 2017:
Houston Electric T&D	$	2,997	(1)	$	—		$	724	$	636		$	10,292			$	924
Natural Gas Distribution	2,606			33			260		348			6,608				523
Energy Services	3,997			52			19		126			1,521				11
Midstream Investments (3)	—			—			—		—			2,472				—
Corporate and Other	14			—			33		26			2,497			(4)	36
Eliminations	—			(85		)	—		—			(654		)		—
Consolidated	$	9,614		$	—		$	1,036	$	1,136		$	22,736			$	1,494
Reconciling items																(68		)
Capital expenditures per Statements of Consolidated Cash Flows																$	1,426


(1)	CenterPoint Energy’s Houston Electric T&D’s revenues from major customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229


(2)	Includes revenues not eliminated in consolidation for pipeline construction and repair services of $162 million capitalized by CenterPoint Energy’s NGD for the 11 months ended December 31, 2019. See Note 2(b).


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



	Year Ended December 31,
	2019		2018		2016
	(in millions)
Enable	$	229	$	307	$	265


(4)	Total assets included pension and other postemployment-related regulatory assets of $584 million, $665 million and $600 million as of December 31, 2019, 2018 and 2017, respectively. 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.

Houston Electric

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

included.


(1)	Houston Electric’s revenues from major external customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229

CERC



	Revenues from External Customers		Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets (1)			Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2019:
Natural Gas Distribution	$	2,911	$	40		$	289	$	316		$	7,497		$	773
Energy Services	3,654		128			16		32			1,301			12
Other Operations	5		—			—		2			149			—
Eliminations	—		(168		)	—		—			(508		)	—
Consolidated	$	6,570	$	—		$	305	$	350		$	8,439		$	785
Reconciling items														(9		)
Capital expenditures per Statements of Consolidated Cash Flows														$	776
As of and for the year ended December 31, 2018:
Natural Gas Distribution	$	2,931	$	36		$	277	$	266		$	6,956		$	638
Energy Services	4,411		110			16		(47		)	1,558			20
Other Operations	1		—			—		3			66			—
Eliminations	—		(146		)	—		—			(366		)	—
Consolidated	$	7,343	$	—		$	293	$	222		$	8,214		$	658
Reconciling items														(25		)
Capital expenditures per Statements of Consolidated Cash Flows														$	633



	Revenues from External Customers		Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets (1)				Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2017:
Natural Gas Distribution	$	2,606	$	33		$	260	$	348		$	6,608			$	523
Energy Services	3,997		52			19		126			1,521				11
Discontinued operations	—		—			—		—			2,472			(1)	—
Other Operations	—		—			—		(7		)	70				—
Eliminations	—		(85		)	—		—			(559		)		—
Consolidated	$	6,603	$	—		$	279	$	467		$	10,112			$	534
Reconciling items															(21		)
Capital expenditures per Statements of Consolidated Cash Flows															$	513

(1)

On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 11.

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

CenterPoint Energy’s Houston Electric T&D’s revenues from major customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229

Midstream Investments [Table Text Block]

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



	Year Ended December 31,
	2019		2018		2016
	(in millions)
Enable	$	229	$	307	$	265

Revenues by Products and Services [Table Text Block]



	Year Ended December 31,
	2019						2018						2017
Revenues by Products and Services:	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Electric delivery	$	3,019	$	2,990	$	—	$	3,232	$	3,234	$	—	$	2,997	$	2,998	$	—
Retail electric sales	486		—		—		—		—		—		—		—		—
Wholesale electric sales	14		—		—		—		—		—		—		—		—
Retail gas sales	4,802		—		4,070		4,161		—		4,161		3,634		—		3,634
Wholesale gas sales	2,312		—		2,313		3,008		—		3,008		2,811		—		2,811
Gas transportation and processing	33		—		33		32		—		32		29		—		29
Infrastructure services	1,186		—		—		—		—		—		—		—		—
Energy products and services	449		—		154		156		—		142		143		—		129
Total	$	12,301	$	2,990	$	6,570	$	10,589	$	3,234	$	7,343	$	9,614	$	2,998	$	6,603

Revenue Recognition (Tables)

12 Months Ended

Dec. 31, 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



	Year Ended December 31, 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	$	2,984		$	523	$	3,680		$	479		$	1,190		$	295	$	9,151
Derivatives income	6			—		2			3,303			—			—		3,311
Other (3)	6			—		1			—			—			5		12
Eliminations	—			—		(40		)	(129		)	(4		)	—		(173		)
Total revenues	$	2,996		$	523	$	3,643		$	3,653		$	1,186		$	300	$	12,301

	Year Ended December 31, 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	$	3,235		$	—	$	3,011		$	493		$	—		$	6	$	6,745
Derivatives income	(2		)	—		(2		)	4,028			—			—		4,024
Other (3)	(1		)	—		(42		)	—			—			9		(34		)
Eliminations	—			—		(36		)	(110		)	—			—		(146		)
Total revenues	$	3,232		$	—	$	2,931		$	4,411		$	—		$	15	$	10,589

	Year Ended December 31, 2017
	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	$	3,001		$	—	$	2,638		$	480		$	—		$	5	$	6,124
Derivatives income	(1		)	—		—			3,569			—			—		3,568
Other (3)	(3		)	—		1			—			—			9		7
Eliminations	—			—		(33		)	(52		)	—			—		(85		)
Total revenues	$	2,997		$	—	$	2,606		$	3,997		$	—		$	14	$	9,614


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


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

(3)


(4)	Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to December 31, 2019.

Houston Electric



	Year Ended December 31,
	2019		2018			2017
	(in millions)
Revenue from contracts	$	2,984	$	3,235		$	3,001
Other (1)	6		(1		)	(3		)
Total revenues	$	2,990	$	3,234		$	2,998

(1)

CERC



	Year Ended December 31, 2019
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,945		$	480		$	5	$	3,430
Derivatives income	2			3,302			—		3,304
Other (3)	4			—			—		4
Eliminations	(40		)	(128		)	—		(168		)
Total revenues	$	2,911		$	3,654		$	5	$	6,570

	Year Ended December 31, 2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	3,011		$	493		$	1	$	3,505
Derivatives income	(2		)	4,028			—		4,026
Other (3)	(42		)	—			—		(42		)
Eliminations	(36		)	(110		)	—		(146		)
Total revenues	$	2,931		$	4,411		$	1	$	7,343

	Year Ended December 31, 2017
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)
Revenue from contracts	$	2,638		$	480		$	—	$	3,118
Derivatives income	—			3,569			—		3,569
Other (3)	1			—			—		1
Eliminations	(33		)	(52		)	—		(85		)
Total revenues	$	2,606		$	3,997		$	—	$	6,603


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


(2)	Reflected in Non-utility revenues in the 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)	$	516	$	373	$	—	$	3
Closing balance as of December 31, 2019	800		579		61		34
Increase	$	284	$	206	$	61	$	31


(1)	Opening balances related to Vectren are as of February 1, 2019, and are thus excluded from the opening balance as of December 31, 2018.

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 December 31, 2019	210			117		3
Increase (decrease)	$	(24	)	$	7	$	—

CERC



	Accounts Receivable		Other Accrued Unbilled Revenues
	(in millions)
Opening balance as of December 31, 2018	$	282	$	263
Closing balance as of December 31, 2019	282		250
Increase (decrease)	$	—	$	(13	)

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 December 31, 2019:
Infrastructure Services	$	254	$	—	$	254
Corporate and Other	84		752		836
	$	338	$	752	$	1,090

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Use of Estimates

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.

Principles of Consolidation

The accounts of the Registrants and their wholly-owned and majority-owned and controlled subsidiaries are included in the consolidated financial statements. All intercompany transactions and balances are eliminated in consolidation, except as described below.

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. Fees incurred by CenterPoint Energy’s and CERC’s NGD for pipeline construction and repair services that were capitalized totaled $162 million and $20 million, respectively, for the 11 months ended December 31, 2019.

As of December 31, 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.

Equity and Investments without a Readily Determinable Fair Value (CenterPoint Energy and CERC)

Equity and Investments without a Readily Determinable Fair Value (CenterPoint Energy)

CenterPoint Energy generally uses the equity method of accounting for investments in entities in which it has an ownership interest between 20% and 50% and exercises significant influence. CenterPoint Energy also uses the equity method for investments in which it has ownership percentages greater than 50%, when it exercises significant influence, does not have control and is not considered the primary beneficiary, if applicable.

Under the equity method, CenterPoint Energy adjusts its investments each period for contributions made, distributions received, respective shares of comprehensive income and amortization of basis differences, as appropriate. CenterPoint Energy evaluates its equity method investments for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.

CenterPoint Energy considers distributions received from equity method investments which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and classifies these distributions as operating activities in its Statements of Consolidated Cash Flows. CenterPoint Energy considers distributions received from equity method investments in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and classifies these distributions as investing activities in its Statements of Consolidated Cash Flows.

Investments without a readily determinable fair value will be measured at cost, less impairment, plus or minus observable prices changes of an identical or similar investment of the same issuer.

Long-lived Assets, Goodwill and Intangibles

The Registrants record revenue for electricity delivery and natural gas sales and services under the accrual method and these revenues are recognized upon delivery to customers. Electricity deliveries not billed by month-end are accrued based on actual AMS data, daily supply volumes and applicable rates. Natural gas sales not billed by month-end are accrued based upon estimated purchased gas volumes, estimated lost and unaccounted for gas and currently effective tariff rates. Revenue for some pipeline construction services are based on the percentage of completion method. For further discussion, see Note 5.

MISO Transactions

Indiana Electric is a member of the 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 Statements of Consolidated Income in Utility natural gas, fuel and purchased power, and net sales within that interval are recorded on CenterPoint Energy’s 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.

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 16(c) and (d).

The Registrants record property, plant and equipment at historical cost and expense repair and maintenance costs as incurred.

The Registrants periodically evaluate long-lived assets, including property, plant and equipment, and specifically identifiable intangibles subject to amortization, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. For rate regulated businesses, recoverability of long-lived assets is assessed by determining if a capital disallowance from a regulator is probable through monitoring the outcome of rate cases and other proceedings. For non-rate regulated businesses, recoverability is assessed based on an estimate of undiscounted cash flows attributable to the assets compared to the carrying value of the assets. As of December 31, 2019, CenterPoint Energy and CERC, as applicable, determined that the carrying value of long-lived and intangible assets associated with the Infrastructure Services and Energy Services reporting units were recoverable based on undiscounted cash flows, considering the likelihood of possible outcomes existing as of that date, including the assessment of the likelihood of a future sale of these assets. No long-lived asset or intangible asset impairments were recorded in 2019, 2018 or 2017.

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. Subsequent to the Registrant’s adoption of ASU 2017-04 Simplifying the Test for Goodwill Impairment on January 1, 2018, CenterPoint Energy and CERC recognize a goodwill impairment by the amount a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill within that reporting unit. CenterPoint Energy includes deferred tax assets and liabilities within its reporting unit’s carrying value for the purposes of annual and interim impairment tests, regardless of whether the estimated fair value reflects the disposition of such assets and liabilities. For further information about the goodwill impairment tests during 2019, see Note 6.

Assets Held for Sale and Discontinued Operations

Generally, a long-lived asset to be sold is classified as held for sale in the period in which management, with approval from the Board of Directors, as applicable, commits to a plan to sell and a sale is expected to be completed within one year. The Registrants record assets and liabilities held for sale at the lower of their carrying value or their estimated fair value less cost to sell. If the disposal group reflects a component of a reporting unit and meets the definition of a business, the goodwill within that reporting unit is allocated to the disposal group based on the relative fair value of the components representing a business that will be retained and disposed. Goodwill is not allocated to a portion of a reporting unit that does not meet the definition of a business. A disposal group that meets the held for sale criteria and also represents a strategic shift to the Registrant, is also reflected as discontinued operations on the Statements of Consolidated Income, and prior periods are recast to reflect the earnings or losses from such businesses as income from discontinued operations, net of tax.

Regulatory Assets and Liabilities

The Registrants apply the guidance for accounting for regulated operations to the Houston Electric T&D reportable segment, Indiana Electric Integrated segment and the Natural Gas Distribution reportable segment. The Registrants’ rate-regulated subsidiaries may collect revenues subject to refund pending final determination in rate proceedings. In connection with such revenues, estimated rate refund liabilities are recorded which reflect management’s current judgment of the ultimate outcomes of the proceedings.

The Registrants’ rate-regulated businesses recognize removal costs as a component of depreciation expense in accordance with regulatory treatment. In addition, a portion of the amount of removal costs collected from customers that relate to AROs has been reflected as an asset retirement liability in accordance with accounting guidance for AROs.

For further detail on the Registrants’ regulatory assets and liabilities, see Note 7.

Depreciation and Amortization Expense

The Registrants compute depreciation and amortization using the straight-line method based on economic lives or regulatory-mandated recovery periods. Amortization expense includes amortization of certain regulatory assets and other intangibles.

Capitalization of Interest and AFUDC

The Registrants capitalize interest and AFUDC as a component of projects under construction and amortize it over the assets’ estimated useful lives once the assets are placed in service. AFUDC represents the composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction for subsidiaries that apply the guidance for accounting for regulated operations. Although AFUDC increases both utility plant and earnings, it is realized in cash when the assets are included in rates.



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Interest and AFUDC debt (1)	$	36	$	8	$	3	$	8	$	6	$	2	$	9	$	6	$	2
AFUDC equity (2)	22		15		3		12		10		2		11		10		1


(1)	Included in Interest and other finance charges on the Registrants’ respective Statements of Consolidated Income.

(2)

Included in Other Income (Expense) on the Registrants’ respective Statements of Consolidated Income.

Income Taxes

Houston Electric and CERC are included in CenterPoint Energy’s U.S. federal consolidated income tax return. Houston Electric and CERC report their income tax provision on a separate entity basis pursuant to a tax sharing agreement with CenterPoint Energy. Current federal and certain state income taxes are payable to or receivable from CenterPoint Energy.

The Registrants use the asset and liability method of accounting for deferred income taxes. Deferred income tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. A valuation allowance is established against deferred tax

assets for which management believes realization is not considered to be more likely than not. The Registrants recognize interest and penalties as a component of income tax expense (benefit), as applicable, in their respective Statements of Consolidated Income. CenterPoint Energy reports the income tax provision associated with its interest in Enable in income tax expense (benefit) in its Statements of Consolidated Income.

On December 22, 2017, President Trump signed into law comprehensive tax reform legislation informally called the Tax Cuts and Jobs Acts, or TCJA, which resulted in significant changes to federal tax laws effective January 1, 2018. See Note 15 for further discussion of the impacts of tax reform implementation.

To the extent certain EDIT of the Registrants’ rate-regulated subsidiaries may be recoverable or payable through future rates, regulatory assets and liabilities have been recorded, respectively.

The Registrants use the portfolio approach to recognize income tax effects on other comprehensive income from accumulated other comprehensive income.

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

Accounts Receivable and Allowance for Doubtful Accounts

Accounts receivable are recorded at the invoiced amount and do not bear interest. Management reviews the outstanding accounts receivable, as well as the bad debt write-offs experienced in the past, and establishes an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered.

The table below summarizes the Registrants’ provision for doubtful accounts for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Provision for doubtful accounts	$	16	$	—	$	12	$	16	$	—	$	16	$	14	$	1	$	13

Inventory

The Registrants’ inventory consists principally of materials and supplies, and for CERC, natural gas, and for CenterPoint Energy, coal inventory. Materials and supplies are valued at the lower of average cost or market. Materials and supplies are recorded to inventory when purchased and subsequently charged to expense or capitalized to plant when installed. Natural gas inventories of CERC’s Energy Services reportable segment at locations qualifying for and utilizing the fair value hedge accounting election are valued at fair value; inventories at locations not qualifying for or not utilizing the fair value hedge accounting election are valued at the lower of average cost or market. During 2019, 2018 and 2017, CERC recorded write-downs of natural gas inventory to the lower of average cost or market which are disclosed on the respective Statements of Consolidated Cash Flows.

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. Such derivatives are recognized in the Registrants’ Consolidated Balance Sheets at their fair value unless the Registrant elects the normal purchase and sales exemption for qualified physical transactions. A derivative may be designated as a normal purchase or normal sale if the intent is to physically receive or deliver the product for use or sale in the normal course of business. CenterPoint Energy and CERC have elected to record changes in the fair value of amounts excluded from the assessment of effectiveness immediately in their Statements of Consolidated Income.

CenterPoint Energy has a Risk Oversight Committee composed of corporate and reportable segment officers that oversees commodity price, weather and credit risk activities, including the Registrants’ marketing, risk management services and hedging activities. The committee’s duties are to establish the Registrants’ commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions and ensure compliance with the Registrants’ risk

management policies and procedures and limits established by CenterPoint Energy’s Board of Directors. The Registrants’ policies prohibit the use of leveraged financial instruments. A leveraged financial instrument, for this purpose, is a transaction involving a derivative whose financial impact will be based on an amount other than the notional amount or volume of the instrument.

Investments in Equity Securities (CenterPoint Energy and CERC)

CenterPoint Energy and CERC report equity securities at estimated fair value in their respective Consolidated Balance Sheets, and any unrealized holding gains and losses are recorded as Other Income (Expense) in their respective Statements of Consolidated Income.

Environmental Costs

The Registrants expense or capitalize environmental expenditures, as appropriate, depending on their future economic benefit. The Registrants expense amounts that relate to an existing condition caused by past operations that do not have future economic benefit. The Registrants record undiscounted liabilities related to these future costs when environmental assessments and/or remediation activities are probable and the costs can be reasonably estimated.

Cash and Cash Equivalents and Restricted Cash

For purposes of reporting cash flows, the Registrants consider cash equivalents to be short-term, highly-liquid investments with maturities of three months or less from the date of purchase. Cash and cash equivalents held by the Bond Companies (VIEs) solely to support servicing the Securitization Bonds as of December 31, 2019 and 2018 are reflected on CenterPoint Energy’s and Houston Electric’s Consolidated Balance Sheets.

In connection with the issuance of Securitization Bonds, CenterPoint Energy and Houston Electric were required to establish restricted cash accounts to collateralize the bonds that were issued in these financing transactions. These restricted cash accounts are not available for withdrawal until the maturity of the bonds and are not included in cash and cash equivalents. For more information on restricted cash see Note 20

Preferred Stock Dividends

Preferred Stock and Dividends

Preferred stock is evaluated to determine balance sheet classification, and all conversion and redemption features are evaluated for bifurcation treatment. Proceeds received net of issuance costs are recognized on the settlement date. Cash dividends become a liability once declared. Income available to common stockholders is computed by deducting from net income the dividends accumulated and earned during the period on cumulative preferred stock.

Purchase Accounting

The Registrants evaluate acquisitions to determine when a set of acquired activities and assets represent a business. When control of a business is obtained, the Registrants apply the acquisition method of accounting and record the assets acquired, liabilities assumed and any non-controlling interest obtained based on fair value at the acquisition date. The excess of the fair value of purchase consideration over the fair value of the net assets acquired is recorded as goodwill. The results of operations of the acquired business are included in the Registrants’ respective Statements of Consolidated Income beginning on the date of the acquisition.

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 will result in an immaterial adjustment to the carrying value of the Registrants’ accounts receivable, net. The adoption of this standard will not 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 10 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’ consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ statements of consolidated income. The adoption of this standard will not 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.

Income Taxes Merger with Vectren (Details) - USD ($) $ in Millions		12 Months Ended
	Feb. 01, 2019	Dec. 31, 2019
Vectren [Member]
Business Acquisition [Line Items]
Cash paid to acquire Vectren	$ 6,000	$ 5,982
Operating loss carryforwards		177
Charitable Contribution [Member]
Business Acquisition [Line Items]
Deferred tax assets tax credit carryforwards		26
Charitable Contribution [Member] \| Vectren [Member]
Business Acquisition [Line Items]
Deferred tax assets tax credit carryforwards		$ 60

Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2019

Regulated Operations [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 Consolidated Balance Sheets as of December 31, 2019 and 2018. The “amortization through” columns indicate the latest year when a regulatory asset or regulatory liability category will be fully amortized:



	December 31, 2019
	CenterPoint Energy				Houston Electric				CERC
	Amortization Through	(in millions)			Amortization Through	(in millions)			Amortization Through	(in millions)
Regulatory Assets:
Current regulatory assets (1)	2020	$	12		n/a	$	—		2020	$	12
Non-current regulatory assets:
Securitized regulatory assets	2024	788			2024	788			n/a	—
Unrecognized equity return (2)	2024	(168		)	2024	(168		)	n/a	—
Unamortized loss on reacquired debt (3)	2046	62			2046	62			n/a	—
Pension and postretirement-related regulatory asset (3)	Various (a)	637			TBD (b)	34			Various (a)	22
Hurricane Harvey restoration costs (3)	Various	68			TBD (b)	64			TBD (c)	4
Regulatory assets related to TCJA (3) (4)	Various	30			TBD (b)	23			2023	7
Asset retirement obligation (3)	Perpetual	131			Perpetual	26			Perpetual	94
Other regulatory assets-not earning a return (5)	Various (d)	147			Various	57			Various	48
Other regulatory assets	Various	422			Various	29			Various	16
Total non-current regulatory assets		2,117				915				191
Total regulatory assets		2,129				915				203
Regulatory Liabilities:
Current regulatory liabilities (6)	2020	47			n/a	—			2020	47
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	Various	1,582			TBD (b)	821			Various	442
Estimated removal costs	Various	1,429			Various	244			Various	637
Other regulatory liabilities	Various	463			Various	223			Various	140
Total non-current regulatory liabilities		3,474				1,288				1,219
Total regulatory liabilities		3,521				1,288				1,266
Total regulatory assets and liabilities, net		$	(1,392	)		$	(373	)		$	(1,063	)


(a)	Pension and postretirement-related regulatory assets balances are measured annually, and the ending amortization period may change based on the actuarial valuation.


(b)	The recovery and amortization of these amounts are to be determined upon receipt of the final order.


(c)	The recovery and amortization of a portion of these amounts are expected to be determined in the next rate case.


(d)	Other regulatory assets not-earning a return includes items with different amortization periods; therefore, the amortization is accounted for through various periods.



	December 31, 2018
	CenterPoint Energy			Houston Electric			CERC
	(in millions)
Regulatory Assets:
Current regulatory assets (1)	$	77		$	—		$	77
Non-current regulatory assets:
Securitized regulatory assets	1,059			1,059			—
Unrecognized equity return (2)	(213		)	(213		)	—
Unamortized loss on reacquired debt (3)	68			68			—
Pension and postretirement-related regulatory asset (3)	725			33			30
Hurricane Harvey restoration costs (3)	68			64			4
Regulatory assets related to TCJA (3) (4)	33			23			10
Asset retirement obligation (3)	109			24			85
Other regulatory assets-not earning a return (3)	81			55			26
Other regulatory assets	37			11			26
Total non-current regulatory assets	1,967			1,124			181
Total regulatory assets	2,044			1,124			258
Regulatory Liabilities:
Current regulatory liabilities (6)	38			17			21
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	1,323			847			476
Estimated removal costs	886			269			617
Other regulatory liabilities	316			182			134
Total non-current regulatory liabilities	2,525			1,298			1,227
Total regulatory liabilities	2,563			1,315			1,248
Total regulatory assets and liabilities, net	$	(519	)	$	(191	)	$	(990	)


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

(2)



	Year Ended December 31,
	2019				2018				2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric

Allowed equity return recognized	$	45	$	45	$	74	$	74	$	42	$	42


(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. See Note 15 for additional information.


(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 Consolidated Balance Sheets.

Cover Page - USD ($)	12 Months Ended
Cover Page - USD ($)	Dec. 31, 2019	Feb. 19, 2020	Jun. 30, 2019
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Transition Report	false
Entity File Number	1-31447
Entity Registrant Name	CenterPoint Energy, Inc.
Entity Tax Identification Number	74-0694415
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	1111 Louisiana
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	(713)
Local Phone Number	207-1111
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 14,295,717,409
Entity Common Stock, Shares Outstanding		502,243,185
Entity Central Index Key	0001130310
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false
Common Stock, $0.01 par value \| New York Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	CNP
Security Exchange Name	NYSE
Common Stock, $0.01 par value \| Chicago Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	CNP
Security Exchange Name	CHX
Depositary shares, each representing a 1/20th interest in a share of 7.00% Series B Mandatory Convertible Preferred Stock, $0.01 par value \| New York Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	Depositary shares, each representing a 1/20th interest in a share of 7.00% Series B Mandatory Convertible Preferred Stock, $0.01 par value
Trading Symbol	CNP/PB
Security Exchange Name	NYSE
CenterPoint Energy Houston Electric, LLC
Entity Information [Line Items]
Entity File Number	1-3187
Entity Registrant Name	CenterPoint Energy Houston Electric, LLC
Entity Tax Identification Number	22-3865106
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	1111 Louisiana
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	(713)
Local Phone Number	207-1111
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			0
Entity Common Stock, Shares Outstanding		1,000
Entity Central Index Key	0000048732
CenterPoint Energy Houston Electric, LLC \| 9.15% First Mortgage Bonds due 2021 \| New York Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	9.15% First Mortgage Bonds due 2021
Trading Symbol	n/a
Security Exchange Name	NYSE
CenterPoint Energy Houston Electric, LLC \| 6.95% General Mortgage Bonds due 2033 \| New York Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	6.95% General Mortgage Bonds due 2033
Trading Symbol	n/a
Security Exchange Name	NYSE
CenterPoint Energy Resources Corp.
Entity Information [Line Items]
Entity File Number	1-13265
Entity Registrant Name	CenterPoint Energy Resources Corp.
Entity Tax Identification Number	76-0511406
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	1111 Louisiana
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	(713)
Local Phone Number	207-1111
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding		1,000
Entity Central Index Key	0001042773
CenterPoint Energy Resources Corp. \| 6.625% Senior Notes due 2037 \| New York Stock Exchange
Entity Information [Line Items]
Title of 12(b) Security	6.625% Senior Notes due 2037
Trading Symbol	n/a
Security Exchange Name	NYSE

Related Party Transactions (Houston Electric and CERC)

12 Months Ended

Dec. 31, 2019

Related Party Transactions (Houston Electric and CERC)

The table below summarizes money pool activity:



	December 31, 2019						December 31, 2018
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	481		$	—		$	(1	)	$	114
Weighted average interest rate	1.98		%	1.98		%	2.42		%	2.42		%


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

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



	Year Ended December 31,
	2019				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Interest income (expense), net (1)	$	18	$	4	$	1	$	—	$	2	$	—


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

Infrastructure Services provides pipeline construction and repair services to CERC’s NGD. Additionally, CERC, through its subsidiary CES, sells natural gas to Indiana Electric for use in electric generation activities.

Amounts charged for these services are included primarily in Operation and maintenance expenses and amounts billed for natural gas sales are included in Non-utility revenues were as follows:



	Year Ended December 31,
	2019					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	177		$	141	$	190		$	147	$	188		$	128
Net affiliate service charges (billings)	(8		)	8		(17		)	17		(9		)	9
Pipeline construction and repair service charges (1)	—			4		—			—		—			—
Natural gas sales (2)	—			1		—			—		—			—


(1)	Represents charges from Infrastructure Services to CERC’s NGD for the period February 1, 2019 through December 31, 2019.


(2)	Represents sales to Indiana Electric from CES for the period February 1, 2019 through December 31, 2019.

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



	Year Ended December 31,
	2019				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	376	$	120	$	209	$	360	$	180	$	601
Cash contribution from parent	590		129		200		960		—		38
Capital distribution to parent associated with the Internal Spin (1)	—		28		—		1,473		—		—

(1)

The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.

Fair Value Measurements

12 Months Ended

Dec. 31, 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’ 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, and inputs other than quoted prices that are observable for the asset or liability. 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 December 31, 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 $1.44 to $5.20 per MMBtu for CenterPoint Energy and from $1.44 to $5.20 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 December 31, 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 and recognize transfers between levels at the end of the reporting period.

CenterPoint Energy



	December 31, 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	$	825	$	—	$	—	$	—		$	825	$	542	$	—	$	—	$	—		$	542
Investments, including money market funds (2)	49		—		—		—			49		66		—		—		—			66
Natural gas derivatives (3)(4)	—		250		42		(98		)	194		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	874	$	250	$	42	$	(98	)	$	1,068	$	609	$	173	$	47	$	(82	)	$	747



	December 31, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Liabilities
Indexed debt securities derivative	$	—	$	893	$	—	$	—		$	893	$	—	$	601	$	—	$	—		$	601
Interest rate derivatives	—		10		—		—			10		24		—		—		—			24
Natural gas derivatives (3)(4)	—		217		24		(161		)	80		—		191		17		(101		)	107
Hedged portion of natural gas inventory	13		—		—		—			13		—		—		—		—			—
Total liabilities	$	13	$	1,120	$	24	$	(161	)	$	996	$	24	$	792	$	17	$	(101	)	$	732

Houston Electric



	December 31, 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)	$	32	$	—	$	—	$	—	$	32	$	48	$	—	$	—	$	—	$	48
Total assets	$	32	$	—	$	—	$	—	$	32	$	48	$	—	$	—	$	—	$	48
Liabilities
Interest rate derivatives	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24

CERC



	December 31, 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)	—		250		42		(98		)	194		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1
Total assets	$	13	$	250	$	42	$	(98	)	$	207	$	14	$	173	$	47	$	(82	)	$	152
Liabilities
Natural gas derivatives (3)(4)	$	—	$	195	$	24	$	(161	)	$	58	$	—	$	191	$	17	$	(101	)	$	107
Hedged portion of natural gas inventory	13		—		—		—			13		—		—		—		—			—
Total liabilities	$	13	$	195	$	24	$	(161	)	$	71	$	—	$	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:



	December 31, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	63	$	63	$	19	$	19


(2)	Amounts are included in Prepaid and Other Current Assets and Other Assets in the Consolidated Balance Sheets.


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

(4)



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	30		$	30		$	(622	)	$	46		$	(704	)	$	13
Total gains	17			17			30			30			96			47
Total settlements	(22		)	(22		)	(39		)	(39		)	(11		)	(11		)
Transfers into Level 3	(1		)	(1		)	5			5			14			14
Transfers out of Level 3 (1)	(6		)	(6		)	656			(12		)	(17		)	(17		)
Ending balance (2)	$	18		$	18		$	30		$	30		$	(622	)	$	46

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:
	$	12		$	12		$	18		$	18		$	87		$	38


(1)	During 2018, CenterPoint Energy transferred its indexed debt securities derivative from Level 3 to Level 2 to reflect changes in the significance of the unobservable inputs used in the valuation.


(2)	CenterPoint Energy and CERC did not have significant Level 3 purchases or sales during any of the years ended December 31, 2019, 2018 or 2017.

Estimated Fair Value of Financial Instruments



	December 31, 2019						December 31, 2018
	CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	(in millions)
Carrying amount	$	15,093	$	4,950	$	2,546	$	9,140	$	4,717	$	2,371
Fair value	16,067		5,457		2,803		9,308		4,770		2,488


(1)	Includes Securitization Bond debt.

Items measured at Fair Value on a Non-recurring Basis

CenterPoint Energy and CERC recorded a goodwill impairment charge of $48 million related to its Energy Services reporting unit in 2019. See Note 6.

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.

+ References + Details

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2018

Sep. 30, 2018

^[1]

Jun. 30, 2018

^[1]

Mar. 31, 2018

^[1]

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Preferred units - unconsolidated affiliate

$ 363

Percentage of sales that trigger right of first refusal

5.00%

Proceeds from Equity Method Investment, Distribution

$ 261

267

$ 0

Total distributions received from Enable

339

333

Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]

CenterPoint Energy’s equity in earnings, net

230

307

265

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s equity method investment in Enable

2,482

2,408

2,482

Contribution from parent

129

960

Total distributions received from Enable

223

297

Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Income tax expense

104

Income (loss) from discontinued operations, net of tax

(2)

^[1]

$ 44

$ 52

$ 0

138

161

Share Price

$ 10.03

OGE [Member]

Percentage of sales that trigger right of first refusal

5.00%

Non-utility Investments [Member]

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s equity method investment in Enable

^[2]

$ 2

Proliance Holdings LLC [Member]

Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]

CenterPoint Energy’s equity in earnings, net

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s equity method investment in Enable

$ 0

Equity Method Investment Decrease in Carrying Value

$ 61

Equity Method Investment Carrying Value Per Unit

$ 10.29

Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]

^[3],[4]

54.00%

53.70%

54.00%

Operating revenues

$ 2,960

$ 3,431

2,803

Cost of sales, excluding depreciation and amortization

1,279

1,819

1,381

433

398

366

Operating income

569

648

528

Net income attributable to Enable common units

360

485

400

CenterPoint Energy’s interest

193

262

216

Basis difference amortization (1)

^[5]

Loss on dilution, net of proportional basis difference recognition

(11)

(2)

CenterPoint Energy’s equity in earnings, net

^[6],[7]

229

307

$ 265

Equity Method Investment, Summarized Financial Information [Abstract]

Current assets

$ 449

389

449

Non-current assets

11,995

11,877

11,995

Current liabilities

1,615

780

1,615

Non-current liabilities

3,211

4,077

3,211

Non-controlling interest

Preferred equity

362

Equity Method Investment Summarized Financial Information Accumulated Other Comprehensive Income Loss

(3)

Enable partners’ equity

7,218

7,013

7,218

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s ownership interest in Enable partners’ equity

3,896

3,767

3,896

CenterPoint Energy’s basis difference

(1,414)

(1,361)

(1,414)

CenterPoint Energy’s equity method investment in Enable

$ 2,482

$ 2,406

$ 2,482

Enable Midstream Partners [Member] | Common Units [Member]

Distribution per share of common units

$ 1.2970

$ 1.2720

Proceeds from Equity Method Investment, Distribution

$ 303

^[8]

$ 297

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

Distribution per share of Series A preferred units

$ 2.5000

Distributions received from Enable cost method investment

$ 36

Enable Midstream Partners [Member] | CERC Corp [Member] | Common Units [Member]

Distribution per share of common units

^[8]

$ 0.9540

$ 1.2720

Proceeds from Equity Method Investment, Distribution

^[8]

$ 223

$ 297

Common Units [Member] | Enable Midstream Partners [Member]

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

^[4]

233,856,623

Natural Gas Expenses [Member] | Enable Midstream Partners [Member]

Preferred units held

^[4],[9]

14,520,000

Natural gas expenses, including transportation and storage costs (1)

^[10]

$ 120

$ 122

115

Accounts payable for natural gas purchases from Enable

$ 11

Natural Gas Expenses [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]

Natural gas expenses, including transportation and storage costs (1)

^[10]

120

122

115

Accounts payable for natural gas purchases from Enable

Transitional Service [Member] | Enable Midstream Partners [Member]

Reimbursement of support services (2)

^[7]

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

$ 2

^[3]

100.00%

Maximum incentive distribution right

50.00%

Enable Midstream Partners [Member] | OGE [Member]

Enable Midstream Partners [Member] | Public unitholders [Member]

^[3]

25.50%

25.60%

Enable Midstream Partners [Member] | Minimum [Member]

^[3]

20.80%

20.40%

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]

433,232,411

435,201,365

433,232,411

Enable Midstream Partners [Member] | Common Units [Member] | Public unitholders [Member]

110,982,805

Discontinued Operations, Disposed of by Means Other than Sale, Spinoff [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]

88,392,983

90,361,937

88,392,983

Investment in unconsolidated affiliates - discontinued operations

^[11]

2,472

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax

$ 184

265

Income tax expense

104

Income (loss) from discontinued operations, net of tax

$ 138

$ 161

Enable GP, LLC [Member]

50.00%

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

40.00%

^[12],[13]

50.00%

Enable GP, LLC [Member] | OGE [Member]

^[13],[14]

40.00%

^[12]

50.00%

^[14]

60.00%

[1]	Amounts have been recast to reflect discontinued operations in all periods presented.
[2]	Represents the fair value of non-utility equity investments acquired in the Merger.
[3]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[4]	Prior to the Internal Spin completed in September 2018, CenterPoint Energy’s investment in Enable’s common units, excluding the Enable Series A Preferred Units held directly by CenterPoint Energy, was held indirectly through CERC.
[5]	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.
[6]	Equity earnings for the year ended December 31, 2019 includes CenterPoint Energy’s share of Enable’s $86 million goodwill impairment recorded in the fourth quarter of 2019.
[7]	Represents amounts billed for certain support services provided to Enable. Actual support services costs are recorded net of reimbursement.
[8]	Prior to the Internal Spin completed in September 2018, distributions from Enable were received by CERC. After such date, distributions from Enable were received directly by CenterPoint Energy (through CNP Midstream).
[9]	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Consolidated Balance Sheets, was $363 million as of both December 31, 2019 and 2018. No impairment charges or adjustment to carrying value were made as no observable price changes were identified in the current or prior reporting periods.
[10]	Included in Non-utility costs of revenues, including natural gas on CenterPoint Energy’s and CERC’s respective Statements of Consolidated Income.
[11]	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 11.
[12]	As of December 31, 2019, 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.
[13]	Held indirectly through CNP Midstream.
[14]	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.

STATEMENTS OF CONSOLIDATED INCOME (Parentheticals) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
CERC Corp [Member]
Income tax expense (benefit) associated with discontinued operations	$ 0	$ 46	$ 104

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.

+ References + Details

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($)

Dec. 31, 2019

Dec. 31, 2018

^[1]

$ 241,000,000

$ 4,231,000,000

Bad debt reserve

21,000,000

18,000,000

1,249,000,000

1,190,000,000

161,000,000

192,000,000

$ 2,117,000,000

$ 1,967,000,000

Cumulative 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

Common stock authorized (in shares)

1,000,000,000

Common stock outstanding (in shares)

502,242,061

501,197,784

Variable Interest Entity, Primary Beneficiary [Member]

$ 216,000,000

$ 335,000,000

26,000,000

56,000,000

19,000,000

34,000,000

788,000,000

1,059,000,000

^[2]

216,000,000

335,000,000

49,000,000

61,000,000

Houston Electric [Member] | Variable Interest Entity, Primary Beneficiary [Member]

915,000,000

1,124,000,000

216,000,000

335,000,000

Bad debt reserve

1,000,000

26,000,000

56,000,000

19,000,000

34,000,000

788,000,000

1,059,000,000

2,000,000

14,000,000

Bad debt reserve

15,000,000

17,000,000

693,000,000

894,000,000

44,000,000

115,000,000

Cumulative Preferred Stock [Member]

$ 191,000,000

$ 181,000,000

Cumulative preferred stock par value (in dollars per share)

$ 0.01

Cumulative preferred stock authorized (in shares)

20,000,000

Series A Preferred Stock [Member]

Cumulative preferred stock par value (in dollars per share)

$ 0.01

Preferred Stock, Liquidation Preference, Value

$ 800,000,000

Cumulative preferred stock outstanding (in shares)

800,000

Cumulative preferred stock par value (in dollars per share)

$ 0.01

Preferred Stock, Liquidation Preference, Value

$ 977,500,000

Cumulative preferred stock outstanding (in shares)

977,500

[1]

[2]

Mergers and Acquisitions (Tables)

12 Months Ended

Dec. 31, 2019

Business Combinations [Abstract]

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

The following table presents the purchase price allocation as of December 31, 2019 (in millions):



Cash and cash equivalents	$	16
Other current assets	577
Property, plant and equipment, net	5,147
Identifiable intangibles	297
Regulatory assets	338
Other assets	141
Total assets acquired	6,516
Current liabilities	648
Regulatory liabilities	938
Other liabilities	886
Long-term debt	2,401
Total liabilities assumed	4,873
Net assets acquired	1,643
Goodwill	4,339
Total purchase price consideration	$	5,982

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

The fair value of the identifiable intangible assets and related useful lives as included in the purchase price allocation as of December 31, 2019 include:



	Weighted Average Useful Lives	Estimated Fair Value
	(in years)	(in millions)
Operation and maintenance agreements	24	$	12
Customer relationships	18	200
Construction backlog	1	27
Trade names	10	58
Total		$	297

Business Combination, Separately Recognized Transactions [Table Text Block]

The results of operations for Vectren included in CenterPoint Energy’s Consolidated Financial Statements from the Merger Date for the year ended December 31, 2019 are as follows:



	(in millions)
Operating revenues	$	2,729
Net income	190

Business Acquisition, Pro Forma Information [Table Text Block]



	Year Ended December 31,
	2019			2018
	(in millions)
Operating revenues	$	12,547		$	13,282
Net income	812		(1)	458		(2)


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

(2)

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

Income Taxes

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Income Taxes [Text Block]

Income Taxes

The components of the Registrant’ income tax expense (benefit) were as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CenterPoint Energy
Current income tax expense:
Federal	$	48		$	89		$	32
State	21			9			9
Total current expense	69			98			41
Deferred income tax expense (benefit):
Federal	74			(25		)	(806		)
State	(5		)	73			36
Total deferred expense (benefit)	69			48			(770		)
Total income tax expense (benefit)	$	138		$	146		$	(729	)
Houston Electric
Current income tax expense:
Federal	$	84		$	109		$	70
State	20			18			19
Total current expense	104			127			89
Deferred income tax benefit:
Federal	(24		)	(38		)	(98		)
Total deferred benefit	(24		)	(38		)	(98		)
Total income tax expense (benefit)	$	80		$	89		$	(9	)
CERC - Continuing Operations
Current income tax expense (benefit):
Federal	$	—		$	(9	)	$	(31	)
State	7			—			(10		)
Total current expense (benefit)	7			(9		)	(41		)
Deferred income tax expense (benefit):
Federal	39			10			(249		)
State	(32		)	21			25
Total deferred expense (benefit)	7			31			(224		)
Total income tax expense (benefit)	$	14		$	22		$	(265	)
CERC - Discontinued Operations
Current income tax expense (benefit):
Federal	$	—		$	9		$	31
State	—			4			11
Total current expense (benefit)	—			13			42
Deferred income tax expense:
Federal	—			29			56
State	—			4			6
Total deferred expense	—			33			62
Total income tax expense	$	—		$	46		$	104

A reconciliation of income tax expense (benefit) using the federal statutory income tax rate to the actual income tax expense and resulting effective income tax rate is as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CenterPoint Energy (1) (2) (3)
Income before income taxes	$	929		$	514		$	1,063
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	195			108			372
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	36			22			26
State valuation allowance, net of federal income tax	(4		)	11			3
State law change, net of federal income tax	(21		)	32			—
Federal income tax rate reduction	—			—			(1,113		)
Excess deferred income tax amortization	(55		)	(24		)	—
Other, net	(13		)	(3		)	(17		)
Total	(57		)	38			(1,101		)
Total income tax expense (benefit)	$	138		$	146		$	(729	)
Effective tax rate	15		%	28		%	(69		)%
Houston Electric (4) (5) (6)
Income before income taxes	$	436		$	425		$	424
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	92			89			148
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	16			14			12
Federal income tax rate reduction	—			—			(158		)
Excess deferred income tax amortization	(21		)	(9		)	—
Other, net	(7		)	(5		)	(11		)
Total	(12		)	—			(157		)
Total income tax expense (benefit)	$	80		$	89		$	(9	)
Effective tax rate	18		%	21		%	(2		)%
CERC - Continuing Operations (7) (8) (9)
Income before income taxes	$	226		$	92		$	319
Federal statutory income tax rate	21		%	21		%	35		%
Expected federal income tax expense	47			19			112
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	(12		)	5			6
State law change, net of federal income tax	(4		)	—			—
State valuation allowance, net of federal income tax	(4		)	11			3
Federal income tax rate reduction	—			—			(396		)
Goodwill impairment	8			—			—
Excess deferred income tax amortization	(18		)	(15		)	—
Tax basis balance sheet adjustment	—			—			11
Other, net	(3		)	2			(1		)
Total	(33		)	3			(377		)
Total income tax expense (benefit)	$	14		$	22		$	(265	)
Effective tax rate	6		%	24		%	(83		)%



	Year Ended December 31,
	2019			2018			2017
	(in millions)
CERC - Discontinued Operations (9)
Income before income taxes	$	—		$	184		$	265
Federal statutory income tax rate	—		%	21		%	35		%
Expected federal income tax expense	—			39			93
Increase in tax expense resulting from:
State income tax expense, net of federal income tax	—			7			11
Total	—			7			11
Total income tax expense	$	—		$	46		$	104
Effective tax rate	—		%	25		%	39		%

(1)

(2)


(3)	Recognized a $1.1 billion deferred tax benefit from the remeasurement of CenterPoint Energy’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.


(4)	Recognized $21 million of amortization of the net regulatory EDIT liability as decreed by regulators.


(5)	Recognized $9 million of amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions beginning in 2018.


(6)	Recognized a $158 million deferred tax benefit from the remeasurement of Houston Electric’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.

(7)


(8)	Recorded an additional $11 million valuation allowance on certain state net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. This item is partially offset by $15 million of amortization of the net regulatory EDIT liability in certain jurisdictions as decreed by regulators beginning in 2018.

(9)

The tax effects of temporary differences that give rise to significant portions of deferred tax assets and liabilities were as follows:



	December 31,
	2019			2018
	(in millions)
CenterPoint Energy
Deferred tax assets:
Benefits and compensation	$	152		$	160
Regulatory liabilities	447			356
Loss and credit carryforwards	111			84
Asset retirement obligations	89			62
Indexed debt securities derivative	34			—
Other	40			29
Valuation allowance	(25		)	(18		)
Total deferred tax assets	848			673
Deferred tax liabilities:
Property, plant and equipment	2,656			1,894
Investment in unconsolidated affiliates	1,010			987
Regulatory assets	344			395
Investment in marketable securities and indexed debt	586			478
Indexed debt securities derivative	—			27
Other	180			131
Total deferred tax liabilities	4,776			3,912
Net deferred tax liabilities	$	3,928		$	3,239
Houston Electric
Deferred tax assets:
Regulatory liabilities	$	195		$	205
Benefits and compensation	14			17
Asset retirement obligations	9			7
Other	7			12
Total deferred tax assets	225			241
Deferred tax liabilities:
Property, plant and equipment	1,129			1,087
Regulatory assets	126			177
Total deferred tax liabilities	1,255			1,264
Net deferred tax liabilities	$	1,030		$	1,023
CERC - Continuing Operations
Deferred tax assets:
Benefits and compensation	$	24		$	27
Regulatory liabilities	144			150
Loss and credit carryforwards	183			259
Asset retirement obligations	80			54
Other	23			20
Valuation allowance	(15		)	(18		)
Total deferred tax assets	439			492
Deferred tax liabilities:
Property, plant and equipment	821			773
Regulatory assets	45			41
Other	43			84
Total deferred tax liabilities	909			898
Net deferred tax liabilities	$	470		$	406

Merger with Vectren. On Merger Date, pursuant to the Merger Agreement, CenterPoint Energy consummated the Merger and acquired Vectren for approximately $6 billion in cash. On the Merger Date, Vectren became a wholly-owned subsidiary of CenterPoint Energy which triggered an ownership change under Section 382 of the Code. Under this Code section, future utilization of acquired net operating loss carry forwards and other tax attributes can be limited. On the Merger Date, Vectren estimated $177 million and $60 million of federal net operating loss and of charitable contribution carryforwards, respectively, the utilization of which is not expected to be limited under Section 382.

Tax Attribute Carryforwards and Valuation Allowance. CenterPoint Energy has no federal net operating loss carryforwards as of December 31, 2019. Also, CenterPoint Energy has $26 million of federal charitable contribution carryforwards, which have a five-year carryover period. As of December 31, 2019, CenterPoint Energy had $699 million of state net operating loss carryforwards that expire between 2020 and 2039 and $21 million of state tax credits that do not expire. CenterPoint Energy reported a valuation allowance of $25 million because it is more likely than not that the benefit from certain state net operating loss carryforwards will not be realized.

CERC has $618 million of federal net operating loss carryforwards which have an indefinite carryforward period. CERC has $691 million of state net operating loss carryforwards which expire between 2020 and 2039 and $17 million of state tax credits which do not expire. CERC reported a valuation allowance of $15 million since it is more likely than not that the benefit from certain state net operating loss carryforwards will not be realized.

A reconciliation of CenterPoint Energy’s beginning and ending balance of unrecognized tax benefits, excluding interest and penalties, for 2019 is as follows:



	Year Ended December 31, 2019
	(in millions)
Balance, beginning of year	$	—
Unrecognized tax benefits assumed through the Merger	9
Decreases related to tax positions of prior years	(1		)
Balance, end of year	$	8

CenterPoint Energy had no unrecognized tax benefits for 2018 and 2017.

During the year ended December 31, 2019, CenterPoint Energy acquired $9 million of unrecognized tax benefits in connection with the Merger. Included in the balance of uncertain tax positions as of December 31, 2019 are $3 million of tax benefits that, if recognized, would affect the effective tax rate. The above table does not include an immaterial amount of accrued interest as of December 31, 2019. The Registrants recognize interest accrued related to unrecognized tax benefits and penalties as income tax expense. The Registrants believe that it is reasonably possible that a decrease of up to $5 million in unrecognized tax benefits may occur by the end of 2020 as a result of a lapse of statutes on older exposures and/or the filing of applications for accounting method changes. CenterPoint Energy’s net unrecognized tax benefits, including penalties and interest, were $9 million as of December 31, 2019 and are included in other non-current liabilities in the Consolidated Financial Statements.

Tax Audits and Settlements. Tax years through 2017 have been audited and settled with the IRS for CenterPoint Energy. For the 2018 and 2019 tax years, the Registrants are participants in the IRS’s Compliance Assurance Process. Legacy Vectren is not currently under audit with the IRS, and the 2017-2019 tax years are still open.

Subsequent Events

12 Months Ended

Dec. 31, 2019

Subsequent Events [Abstract]

Subsequent Events [Text Block]

Subsequent Events (CenterPoint Energy)

Proposed Divestiture of Infrastructure Services (CenterPoint Energy)

On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Securities Purchase Agreement to sell the businesses within its Infrastructure Services reportable segment to PowerTeam Services. Subject to the terms and conditions of the Securities Purchase Agreement, PowerTeam Services has agreed to purchase all of the outstanding equity interests of VISCO for approximately $850 million, subject to customary adjustments set forth in the Securities Purchase Agreement, including adjustments based on VISCO’s net working capital at closing, indebtedness, cash and cash equivalents and transaction expenses. Per the Securities Purchase Agreement, VISCO will be converted from a wholly-owned corporation to a limited liability company that is disregarded for federal income tax purposes immediately prior to the closing of the transaction resulting in the sale of membership units at closing. The sale will be considered an asset sale for tax purposes requiring the net deferred tax liabilities of approximately $123 million as of December 31, 2019 to be recognized; therefore, any deferred tax assets and liabilities within the reporting unit are not included in the carrying amount of the assets and liabilities that will be transferred to PowerTeam Services.

The completion of the sale is subject to customary closing conditions, including, among others (i) the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Act and (ii) customary conditions regarding the accuracy of the representations and warranties and compliance by the parties in all material respects with their respective obligations under the Securities Purchase Agreement. The Securities Purchase Agreement also includes customary termination provisions, including if the closing of the sale has not occurred on or before June 3, 2020. The sale is not subject to a financing condition and is expected to close in the second quarter of 2020, subject to satisfaction of the foregoing conditions, among other things.

On February18, 2020, CenterPoint Energy received notice from the Federal Trade Commission granting early termination of the waiting period under the Hart-Scott-Rodino Act in connection with the proposed sale of Infrastructure Services.

Proposed Divestiture of Energy Services (CenterPoint Energy and CERC)

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment, to Athena Energy Services. This transaction does not include CEIP and its assets. Subject to the terms and conditions of the Equity Purchase Agreement, Athena Energy Services has agreed to purchase all of the outstanding equity interests of CES for approximately $400 million, subject to customary adjustments set forth in the Equity Purchase Agreement, including adjustments based on CES’s net working capital at closing, indebtedness and transaction expenses. Per the Equity Purchase Agreement, CES will be converted from a wholly-owned corporation to a limited liability company that is disregarded for federal income tax purposes immediately prior to the closing of the transaction resulting in the sale of membership units at closing. The sale will be considered an asset sale

for tax purposes requiring the net deferred tax liabilities of approximately $25 million as of December 31, 2019 to be recognized; therefore, any deferred tax assets and liabilities within the reporting unit are not included in the carrying amount of the assets and liabilities that will be transferred to the buyer.

The completion of the sale is subject to customary closing conditions, including, among others (i) the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Act and (ii) the conversion of CES to a Delaware limited liability company, (iii) the distribution of the equity interests in CenterPoint Energy Intrastate Pipelines, LLC held by CES to CERC Corp. or its affiliates and (iv) customary conditions regarding the accuracy of the representations and warranties and compliance by the parties in all material respects with their respective obligations under the Equity Purchase Agreement. The Equity Purchase Agreement includes customary termination provisions, including if the closing of the transaction has not occurred on or before June 24, 2020.The sale is not subject to a financing condition and is expected to close in the second quarter of 2020, subject to satisfaction of the foregoing conditions, among other things.

CenterPoint Energy Dividend Declarations (CenterPoint Energy)



Equity Instrument	Declaration Date	Record Date	Payment Date	Per Share
Common Stock	February 3, 2020	February 20, 2020	March 12, 2020	$	0.2900
Series A Preferred Stock	February 3, 2020	February 14, 2020	March 2, 2020	30.6250
Series B Preferred Stock	February 3, 2020	February 14, 2020	March 2, 2020	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

February 7, 2020

February 18, 2020

February 25, 2020

0.3305

Enable Series A Preferred Units

February 7, 2020

February 14, 2020

0.6250

Regulatory Matters

12 Months Ended

Dec. 31, 2019

Regulated Operations [Abstract]

Regulatory Accounting [Text Block]

Regulatory Matters



	December 31, 2019
	CenterPoint Energy				Houston Electric				CERC
	Amortization Through	(in millions)			Amortization Through	(in millions)			Amortization Through	(in millions)
Regulatory Assets:
Current regulatory assets (1)	2020	$	12		n/a	$	—		2020	$	12
Non-current regulatory assets:
Securitized regulatory assets	2024	788			2024	788			n/a	—
Unrecognized equity return (2)	2024	(168		)	2024	(168		)	n/a	—
Unamortized loss on reacquired debt (3)	2046	62			2046	62			n/a	—
Pension and postretirement-related regulatory asset (3)	Various (a)	637			TBD (b)	34			Various (a)	22
Hurricane Harvey restoration costs (3)	Various	68			TBD (b)	64			TBD (c)	4
Regulatory assets related to TCJA (3) (4)	Various	30			TBD (b)	23			2023	7
Asset retirement obligation (3)	Perpetual	131			Perpetual	26			Perpetual	94
Other regulatory assets-not earning a return (5)	Various (d)	147			Various	57			Various	48
Other regulatory assets	Various	422			Various	29			Various	16
Total non-current regulatory assets		2,117				915				191
Total regulatory assets		2,129				915				203
Regulatory Liabilities:
Current regulatory liabilities (6)	2020	47			n/a	—			2020	47
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	Various	1,582			TBD (b)	821			Various	442
Estimated removal costs	Various	1,429			Various	244			Various	637
Other regulatory liabilities	Various	463			Various	223			Various	140
Total non-current regulatory liabilities		3,474				1,288				1,219
Total regulatory liabilities		3,521				1,288				1,266
Total regulatory assets and liabilities, net		$	(1,392	)		$	(373	)		$	(1,063	)


(a)	Pension and postretirement-related regulatory assets balances are measured annually, and the ending amortization period may change based on the actuarial valuation.


(b)	The recovery and amortization of these amounts are to be determined upon receipt of the final order.


(c)	The recovery and amortization of a portion of these amounts are expected to be determined in the next rate case.


(d)	Other regulatory assets not-earning a return includes items with different amortization periods; therefore, the amortization is accounted for through various periods.



	December 31, 2018
	CenterPoint Energy			Houston Electric			CERC
	(in millions)
Regulatory Assets:
Current regulatory assets (1)	$	77		$	—		$	77
Non-current regulatory assets:
Securitized regulatory assets	1,059			1,059			—
Unrecognized equity return (2)	(213		)	(213		)	—
Unamortized loss on reacquired debt (3)	68			68			—
Pension and postretirement-related regulatory asset (3)	725			33			30
Hurricane Harvey restoration costs (3)	68			64			4
Regulatory assets related to TCJA (3) (4)	33			23			10
Asset retirement obligation (3)	109			24			85
Other regulatory assets-not earning a return (3)	81			55			26
Other regulatory assets	37			11			26
Total non-current regulatory assets	1,967			1,124			181
Total regulatory assets	2,044			1,124			258
Regulatory Liabilities:
Current regulatory liabilities (6)	38			17			21
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	1,323			847			476
Estimated removal costs	886			269			617
Other regulatory liabilities	316			182			134
Total non-current regulatory liabilities	2,525			1,298			1,227
Total regulatory liabilities	2,563			1,315			1,248
Total regulatory assets and liabilities, net	$	(519	)	$	(191	)	$	(990	)


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

(2)



	Year Ended December 31,
	2019				2018				2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric

Allowed equity return recognized	$	45	$	45	$	74	$	74	$	42	$	42


(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. See Note 15 for additional information.


(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 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 base rate case included:


•	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. The PUCT began deliberating on the PFD (which is prepared by ALJs at a different state agency) during its November 14, 2019 open meeting, but delayed final determination for further consideration. The PUCT again discussed the Houston Electric rate case at its December 13, 2019 open meeting and concluded that the PUCT would consider settlement a reasonable approach to resolving the rate case and noted that Houston Electric had indicated settlement negotiations were already underway. Houston Electric updated the PUCT at its January 16, 2020 open meeting regarding the status of settlement discussions, indicating that the parties were working on a settlement and anticipated a final settlement in the near future. On January 23, 2020, Houston Electric filed a Stipulation and Settlement Agreement with the PUCT, which provides for the following, among other things:


•	an overall revenue requirement increase of approximately $13 million;


•	an ROE of 9.4%;


•	a capital structure of 57.5% debt/42.5% equity;


•	a refund of unprotected EDIT of $105 million plus carrying costs over approximately 30-36 months; and


•	recovery of all retail transmission related costs through the TCRF.

Also, Houston Electric is not required to make a one-time refund of capital recovery from its TCOS and DCRF mechanisms. Future TCOS filings will take into account both ADFIT and EDIT until the final order from Houston Electric’s next base rate proceeding. No rate base items are expected to be written off; however, approximately $12 million in rate case expenses were written off in 2019. A base rate case application must be filed for Houston Electric no later than four years from the date of the PUCT’s final order in the proceeding. Additionally, Houston Electric will not file a DCRF in 2020, nor will a subsequent separate proceeding with the PUCT be instituted regarding EDIT on Houston Electric’s securitized assets.

Furthermore, under the terms of the Stipulation and Settlement Agreement, Houston Electric agreed to adopt certain ring-fencing measures to increase its financial separateness from CenterPoint Energy, which include the following:


•	Houston Electric’s credit agreements and indentures shall not contain cross-default provisions by which a default by CenterPoint Energy or its other affiliates would cause a default at Houston Electric;


•	The financial covenant in Houston Electric’s credit agreement shall not be related to any entity other than Houston Electric. Houston Electric shall not include in its debt or credit agreements any financial covenants or rating agency triggers related to any entity other than Houston Electric;


•	Houston Electric shall not pledge its assets in respect of or guarantee any debt or obligation of any of its affiliates. Houston Electric shall not pledge, mortgage, hypothecate, or grant a lien upon the property of Houston Electric except pursuant to an exception in effect in Houston Electric’s current credit agreement, such as Houston Electric’s first mortgage and general mortgage;


•	Houston Electric shall maintain its own stand-alone credit facility, and Houston Electric shall not share its credit facility with any regulated or unregulated affiliate;


•	Houston Electric shall maintain ratings with all three major credit ratings agencies;


•	Houston Electric shall maintain a stand-alone credit rating;


•	Houston Electric’s first mortgage bonds and general mortgage bonds shall be secured only with assets of Houston Electric;


•	No Houston Electric assets may be used to secure the debt of CenterPoint Energy or its other affiliates;

•

Houston Electric shall not hold out its credit as being available to pay the debt of any affiliates (provided that, for the avoidance of doubt, Houston Electric is not considered to be holding its credit out to pay the debt of affiliates, or in breach of any other ring-fencing measure, with respect to the $68 million of Houston Electric general mortgage bonds that currently serve as collateral for certain outstanding CenterPoint Energy pollution control bonds);


•	Without prior approval of the PUCT, neither CenterPoint Energy nor any affiliate of CenterPoint Energy (excluding Houston Electric) may incur, guarantee, or pledge assets in respect of any incremental new debt that is dependent on: (1) the revenues of Houston Electric in more than a proportionate degree than the other revenues of CenterPoint Energy; or (2) the equity of Houston Electric;


•	Houston Electric shall not transfer any material assets or facilities to any affiliates, other than a transfer that is on an arm’s length basis consistent with the PUCT’s affiliate standards applicable to Houston Electric;


•	Except for its participation in an affiliate money pool, Houston Electric shall not commingle its assets with those of other CenterPoint Energy affiliates;


•	Except for its participation in an affiliate money pool, Houston Electric shall not lend money to or borrow money from CenterPoint Energy; and


•	Houston Electric shall notify the PUCT if its issuer credit rating or corporate credit rating as rated by any of the three major rating agencies falls below investment grade.

The PUCT approved the settlement at its February 14, 2020 open meeting. A final order from the PUCT is currently expected during the first quarter of 2020; however, motions for rehearing, if granted, could result in the order being issued after the first quarter of 2020. The rates are expected to be implemented 45 days after the final order is issued.

CenterPoint Energy and Houston Electric record pre-tax expense for (i) probable disallowances of capital investments and (ii) customer refund obligations and costs deferred in regulatory assets when recovery of such amounts is no longer considered probable.

Commitments and Contingencies

12 Months Ended

Dec. 31, 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 Consolidated Balance Sheets as of December 31, 2019 and 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 December 31, 2019, minimum purchase obligations are approximately:



	CenterPoint Energy		CERC
	(in millions)
2020	$	750	$	533
2021	617		432
2022	418		242
2023	335		182
2024	271		174
2025 and beyond	1,888		1,526

Indiana Electric 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) AMAs (CenterPoint Energy and CERC)

CenterPoint Energy’s and CERC’s NGD has AMAs associated with their utility distribution service in Arkansas, Indiana, Louisiana, Mississippi, Oklahoma and Texas. The AMAs have varying terms, the longest of which expires in 2023. Pursuant to the provisions of the agreements, CenterPoint Energy’s and CERC’s NGD either sells natural gas to the asset manager and agrees to repurchase an equivalent amount of natural gas throughout the year at the same cost, or simply purchases its full natural gas requirements at each delivery point from the asset manager. Generally, AMAs are contracts between CenterPoint Energy’s and CERC’s NGD and an asset manager that are intended to transfer the working capital obligation and maximize the utilization of the assets. In these agreements, CenterPoint Energy’s and CERC’s NGD agrees to release transportation and storage capacity to other parties to manage natural gas storage, supply and delivery arrangements for CenterPoint Energy’s and CERC’s NGD and to use the released capacity for other purposes when it is not needed for CenterPoint Energy’s and CERC’s NGD. CenterPoint Energy’s and CERC’s NGD may receive compensation from the asset manager through payments made over the life of the AMAs. CenterPoint Energy’s and CERC’s NGD has an obligation to purchase their winter storage requirements that have been released to the asset manager under these AMAs.

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 December 31, 2019, there were 62 open surety bonds supporting future performance with an aggregate face amount of approximately $565 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 December 31, 2019, approximately 36% 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 December 31, 2019 and no amounts were recorded on CenterPoint Energy’s Consolidated Balance Sheets.

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 December 31, 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 $499 million as of December 31, 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.

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

In the normal course of business, CES trades natural gas under supply contracts and enters into natural gas related transactions under transportation, storage and other contracts. In connection with these CES business activities, CERC Corp. has issued guarantees to CES counterparties to guarantee the payment of CES obligations. While CES remains wholly-owned by CERC Corp., these guarantees do not represent incremental consolidated obligations, but rather, represent guarantees of CES’s obligations to allow CES to conduct business without posting other forms of assurance. As of December 31, 2019, the face amount of CERC Corp.’s guarantees of CES obligations was approximately $1.8 billion.

A CERC Corp. guarantee primarily has a one- or two-year term, although CERC Corp. would generally not be released from obligations incurred by CES prior to the termination of such guarantee unless the beneficiary of the guarantee affirmatively released CERC Corp. from its obligations under the guarantee. Since CERC Corp. has owned CES, CERC Corp. has not paid any amounts under any guarantees of CES obligations. While there can be no assurance that performance under any of these parent company guarantees will not be required in the future, CenterPoint Energy and CERC consider the likelihood of a material amount being incurred as remote.

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. Under the terms of the Equity Purchase Agreement, Athena Energy Services must generally use reasonable best efforts to replace existing CERC Corp. guarantees with credit support provided by a party other than CERC Corp. as of and after closing of the sale. Additionally, to the extent that CERC Corp. retains any exposure relating to the guarantees of CES obligations 90 days after closing, Athena Energy Services will pay a 3% annualized fee on such exposure, increasing by 1% on an annualized basis every three months.

CenterPoint Energy and CERC recorded no amounts on their respective Consolidated Balance Sheets as of December 31, 2019 and 2018 related to these guarantees.

(e) 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 on all wrongful death and property damage claims and with some personal injury claimants. Additionally, CenterPoint Energy and CERC cooperated with the investigation conducted by the National Transportation Safety Board, which concluded its investigation in December 2019 and issued a report without making any recommendations. Further, CenterPoint Energy and CERC contested and 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.



	December 31, 2019
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	12	$	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 July 2018, Indiana Electric filed a Complaint for Damages and Declaratory Relief against its insurers seeking reimbursement of defense, investigation and pond closure costs incurred to comply with the CCR Rule, and has since reached confidential settlement agreements with its insurers. The proceeds of these settlements will offset costs that have been and will be incurred to close the ponds. 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. 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 December 31, 2019, CenterPoint Energy has recorded an approximate $68 million ARO, which represents the discounted value of future cash flow estimates to close the ponds at A.B. Brown and F.B. Culley. This estimate is subject to change due to the contractual arrangements; continued assessments of the ash, closure methods, and the timing of closure; implications of Indiana Electric’s generation transition plan; changing environmental regulations; and proceeds received from the settlements in the aforementioned insurance proceeding. In addition to these 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 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.

Goodwill and Other Intangibles (CenterPoint Energy and CERC)

12 Months Ended

Dec. 31, 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 December 31, 2019 are as follows:



	December 31, 2018		Additions (1)		Impairment		December 31, 2019
	(in millions)
Indiana Electric Integrated	$	—	$	1,121	$	—	$	1,121
Natural Gas Distribution	746		2,566		—		3,312
Energy Services (2)	110		—		48		62
Infrastructure Services	—		220		—		220
Corporate and Other	11		438		—		449
Total	$	867	$	4,345	$	48	$	5,164


(1)	This represents the allocation of goodwill to reportable segments from the Merger, changes from preliminary amounts previously reported and includes the final determination of fair value for each reportable segment. See Note 4.

(2)

Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012. As of December 31, 2019, CenterPoint Energy and CERC identified a triggering event to perform an interim goodwill impairment test and recognized a goodwill impairment on their Energy Services reporting unit which is included in Goodwill impairment on CenterPoint Energy’s and CERC’s Consolidated Statements of Income.

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



	December 31, 2018		Impairment		December 31, 2019
			(in millions)
Natural Gas Distribution	$	746	$	—	$	746
Energy Services (1)	110		48		62
Corporate and Other	11		—		11
Total	$	867	$	48	$	819


(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 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 estimated fair value of a reporting unit is primarily determined based on an income approach or a weighted combination of income and market approaches. If the carrying amount of the reporting unit 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(g) for further discussion.

CenterPoint Energy and CERC performed the annual goodwill impairment test on July 1 of each of 2019 and 2018 and determined that no goodwill impairment charge was required for any reporting unit in its annual test.

In connection with its preparation of financial statements for the year ended December 31, 2019, CenterPoint Energy and CERC, as applicable, identified triggering events for interim goodwill impairment tests at the Infrastructure Services and Energy Services reporting units. Early stage bids received from market participants during the exploration of strategic alternatives for these businesses at year-end indicated that the fair value of each reporting unit was more likely than not below the carrying value.

On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Securities Purchase Agreement to sell the businesses within its Infrastructure Services reporting unit. Per the Securities Purchase Agreement, VISCO will be converted from a wholly-owned corporation to a limited liability company that is disregarded for federal income tax purposes immediately prior to the closing of the transaction resulting in the sale of membership units at closing. The sale will be considered an asset sale for tax purposes requiring the net deferred tax liabilities of approximately $123 million within the reporting unit as of December 31, 2019 to be recognized as a benefit to deferred income tax expense by CenterPoint Energy upon closing; therefore, any deferred tax assets and liabilities within the reporting unit are not included in the carrying amount of the assets and liabilities that will be transferred to the buyer. For further information, see Note 23.

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reporting unit. Per the Equity Purchase Agreement, CES will be converted from a wholly-owned corporation to a limited liability company that is disregarded for federal income tax purposes immediately prior to the closing of the transaction resulting in the sale of membership units at closing. For further information, see Note 23.

The fair value of the Infrastructure Services reporting unit was estimated using a market approach deriving an estimated fair value as of December 31, 2019 based on the economic terms agreed upon within the Securities Purchase Agreement, a Level 2 fair value measurement. As of December 31, 2019 the fair value of the Infrastructure Services reporting unit exceeded the carrying value (inclusive of deferred income tax liabilities of $123 million) and no impairment loss was recognized.

The fair value of the Energy Services reporting unit was estimated using a combination of the market approach and the income approach as of December 31, 2019, a Level 3 fair value measurement. CenterPoint Energy and CERC utilized the economic indicators of value received by market participants during the exploration of strategic alternatives to inform the fair value of substantially all of the businesses within this reporting unit as of December 31, 2019. Certain assets groups not constituting a business within the reporting unit were valued using an income approach. CenterPoint Energy and CERC recognized an impairment loss on their Energy Services reporting unit of $48 million, the amount by which the carrying value (inclusive of deferred income tax liabilities of $25 million) exceeded the fair value as of December 31, 2019.

The tables below present information on CenterPoint Energy’s other intangible assets recorded in Intangible assets, net on the Consolidated Balance Sheets and the related amortization expense included in Depreciation and amortization on CenterPoint Energy’s Statements of Consolidated Income, unless otherwise indicated.



	December 31, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships (1)	$	286	$	(43	)	$	243	$	86	$	(27	)	$	59
Covenants not to compete	4		(4		)	—		4		(3		)	1
Trade names (1)	58		(5		)	53		—		—			—
Construction backlog (1) (2)	27		(23		)	4		—		—			—
Operation and maintenance agreements (1) (2)	12		(1		)	11		—		—			—
Other (1)	24		(14		)	10		16		(11		)	5
Total	$	411	$	(90	)	$	321	$	106	$	(41	)	$	65


(1)	The fair value of intangible assets acquired through acquisitions has been finalized. See Note 4.


(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 Statements of Consolidated Income.



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)	$	25	$	10	$	13
Amortization expense of intangible assets recorded in Non-utility cost of revenues, including natural gas (2)	24		—		—


(1)	Includes $17 million for the year ended December 31, 2019 of amortization expense related to intangibles acquired in the Merger.


(2)	The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the year ended December 31, 2019, has been finalized. See Note 4.

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



	December 31, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships	$	86	$	(32	)	$	54	$	86	$	(27	)	$	59
Covenants not to compete	4		(4		)	—		4		(3		)	1
Other	16		(14		)	2		16		(11		)	5
Total	$	106	$	(50	)	$	56	$	106	$	(41	)	$	65



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	9	$	10	$	13

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)
2020	$	29	$	6
2021	25		6
2022	25		6
2023	24		5
2024	22		5

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

12 Months Ended

Dec. 31, 2019

Indexed Debt 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

(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 December 31, 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:



	December 31,
	2019	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 reference shares attributable to the ZENS. The principal amount of the ZENS is subject to increases or decreases to the extent that the annual yield from interest and cash dividends on the reference shares is less than or more than 2.309%. The adjusted principal amount is defined in the ZENS instrument as “contingent principal.” As of December 31, 2019, the ZENS, having an original principal amount of $828 million and a contingent principal amount of $75 million, were outstanding and were exchangeable, at the option of the holders, for cash equal to 95% of the market value of the reference shares attributable to the ZENS. As of December 31, 2019, the market value of such shares was approximately $822 million, which would provide an exchange amount of $944 for each $1,000 original principal amount of ZENS. At maturity of the ZENS in 2029, CenterPoint Energy will be obligated to pay in cash the higher of the contingent principal amount of the ZENS or an amount based on the then-current market value of the reference shares, which will include any additional publicly-traded securities distributed with respect to the current reference shares prior to maturity.

The ZENS obligation is bifurcated into a debt component and a derivative component (the holder’s option to receive the appreciated value of the reference shares at maturity). The bifurcated debt component accretes through interest charges annually up to the contingent principal amount of the ZENS in 2029. Such accretion will be reduced by annual cash interest payments, as described above. The derivative component is recorded at fair value and changes in the fair value of the derivative component are recorded in CenterPoint Energy’s Statements of Consolidated Income. Changes in the fair value of the ZENS-Related Securities held by CenterPoint Energy are expected to substantially offset changes in the fair value of the derivative component of the ZENS.

The following table sets forth summarized financial information regarding CenterPoint Energy’s investment in ZENS-Related Securities and each component of CenterPoint Energy’s ZENS obligation.



	ZENS-Related Securities			Debt Component of ZENS			Derivative Component of ZENS
	(in millions)
Balance as of December 31, 2016	$	953		$	114		$	717
Accretion of debt component of ZENS	—			27			—
2% interest paid	—			(17		)	—
Distribution to ZENS holders	—			(2		)	—
Gain on indexed debt securities	—			—			(49		)
Gain on ZENS-Related Securities	7			—			—
Balance as of December 31, 2017	960			122			668
Accretion of debt component of ZENS	—			21			—
2% interest paid	—			(17		)	—
Sale of ZENS-Related Securities	(398		)	—			—
Distribution to ZENS holders	—			(102		)	(46		)
Gain on indexed debt securities	—			—			(21		)
Loss on ZENS-Related Securities	(22		)	—			—
Balance as of December 31, 2018	540			24			601
Accretion of debt component of ZENS	—			17			—
2% interest paid	—			(17		)	—
Distribution to ZENS holders	—			(5		)	—
Loss on indexed debt securities	—			—			292
Gain on ZENS-Related Securities	282			—			—
Balance as of December 31, 2019	$	822		$	19		$	893

STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net income	$ 791	$ 368	$ 1,792
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans	12	(10)	6
Net deferred gain (loss) from cash flow hedges	(2)	(15)	(3)
Reclassification of deferred loss from cash flow hedges realized in net income (net of tax expense of $-0-, $-0- and $-0-, respectively)	1	0	0
Other comprehensive loss from unconsolidated affiliates, net of tax	(1)	0	0
Other comprehensive income (loss)	10	(25)	3
Comprehensive income	801	343	1,795
Preferred stock dividend requirement	117	35	0
Comprehensive income	684	308	1,795
Houston Electric [Member]
Net income	356	336	433
Other comprehensive income (loss):
Net deferred gain (loss) from cash flow hedges	(1)	(14)	(1)
Other comprehensive income (loss)	(1)	(14)	(1)
Comprehensive income	355	322	432
CERC Corp [Member]
Net income	212	208	745
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans	5	1	4
Net deferred gain (loss) from cash flow hedges	0	(1)	(1)
Other comprehensive income (loss)	5	0	3
Comprehensive income	$ 217	$ 208	$ 748

Subsequent Events (Tables)

12 Months Ended

Dec. 31, 2019

Subsequent Events [Abstract]

Schedule of Subsequent Events [Table Text Block]

CenterPoint Energy Dividend Declarations (CenterPoint Energy)



Equity Instrument	Declaration Date	Record Date	Payment Date	Per Share
Common Stock	February 3, 2020	February 20, 2020	March 12, 2020	$	0.2900
Series A Preferred Stock	February 3, 2020	February 14, 2020	March 2, 2020	30.6250
Series B Preferred Stock	February 3, 2020	February 14, 2020	March 2, 2020	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

February 7, 2020

February 18, 2020

February 25, 2020

0.3305

Enable Series A Preferred Units

February 7, 2020

February 14, 2020

0.6250

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

12 Months Ended

Dec. 31, 2019

USD ($)

Bcf

Dec. 31, 2018

USD ($)

Bcf

Dec. 31, 2017

USD ($)

Energy Related Derivative [Member]

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

Derivative gross volume notional amount (in Bcf) | Bcf

2,226

1,674

Gross Amounts Offset in the Consolidated Balance Sheets

^[1]

$ 51

$ 12

Net Amount Presented in the Consolidated Balance Sheets

^[2]

114

292

220

1,144

833

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

(13)

Income Statement Impact of Derivative Activity [Abstract]

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

^[3]

4,029

4,364

$ 3,785

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

(78)

(123)

260

Derivative, Credit Risk Related Contingent Features [Abstract]

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

Credit Risk Derivatives, at Fair Value, Net [Abstract]

Energy Marketers [Member]

^[4]

194

138

Credit Risk Derivatives, at Fair Value, Net [Abstract]

Retail End Users [Member]

^[4]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

External Credit Rating, Investment Grade [Member]

^[4],[5]

178

114

Credit Risk Derivatives, at Fair Value, Net [Abstract]

External Credit Rating, Investment Grade [Member] | Energy Marketers [Member]

^[6]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

External Credit Rating, Investment Grade [Member] | Retail End Users [Member]

^[6]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

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

^[5],[6]

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

^[2]

136

100

(13)

^[1]

224

166

Other Noncurrent Assets [Member] | Energy Related Derivative [Member]

(88)

(66)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[2]

^[1]

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

(10)

(16)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[1]

(187)

(183)

136

Other Noncurrent Liabilities [Member] | Energy Related Derivative [Member]

^[2]

(51)

(102)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[1]

(54)

(25)

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

^[2]

(29)

(5)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

139

103

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

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

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

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

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

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

184

173

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

893

601

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

Long [Member] | Energy Related Derivative [Member]

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

$ 54

$ 25

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

Derivative gross volume notional amount (in Bcf) | Bcf

374

140

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

$ 0

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

$ 0

$ 24

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

Derivative gross volume notional amount (in Bcf) | Bcf

2,226

1,674

Gross Amounts Offset in the Consolidated Balance Sheets

^[1]

$ 73

$ 12

Net Amount Presented in the Consolidated Balance Sheets

^[2]

136

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

292

220

219

208

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

(13)

Income Statement Impact of Derivative Activity [Abstract]

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

^[3]

3,503

4,364

3,785

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

214

107

211

Derivative, Credit Risk Related Contingent Features [Abstract]

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

Credit Risk Derivatives, at Fair Value, Net [Abstract]

CERC Corp [Member] | Energy Marketers [Member]

^[4]

194

138

Credit Risk Derivatives, at Fair Value, Net [Abstract]

CERC Corp [Member] | Retail End Users [Member]

^[4]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

CERC Corp [Member] | External Credit Rating, Investment Grade [Member]

^[4],[5]

178

114

Credit Risk Derivatives, at Fair Value, Net [Abstract]

CERC Corp [Member] | External Credit Rating, Investment Grade [Member] | Energy Marketers [Member]

^[6]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

CERC Corp [Member] | External Credit Rating, Investment Grade [Member] | Retail End Users [Member]

^[6]

Credit Risk Derivatives, at Fair Value, Net [Abstract]

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

^[5],[6]

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

^[2]

136

100

(13)

^[1]

224

166

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

(88)

(66)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[2]

^[1]

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

(10)

(16)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[1]

(180)

(183)

136

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

^[2]

(44)

(102)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^[1]

(39)

(25)

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

^[2]

(14)

(5)

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^{[10],[11],[12]}

139

103

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

^{[10],[11],[12]}

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^{[10],[11],[12]}

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

^{[10],[11],[12]}

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^{[10],[11],[12]}

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

^{[10],[11],[12]}

177

173

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^{[10],[11],[12]}

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

^{[10],[11],[12]}

$ 39

$ 25

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

Derivative gross volume notional amount (in Bcf) | Bcf

374

140

Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Current Liabilities [Member] | Interest Rate Contract [Member]

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

$ 0

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

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

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

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

Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]

^{[10],[11],[12]}

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

^{[10],[11],[12]}

Income Statement Impact of Derivative Activity [Abstract]

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

214

107

211

Natural Gas Expenses [Member] | Fair Value Hedging [Member] | Energy Related Derivative [Member]

Income Statement Impact of Derivative Activity [Abstract]

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

^[3]

(14)

(13)

Amounts excluded from effectiveness testing recognized in earnings immediately

^[3]

(213)

(149)

(67)

Natural Gas Expenses [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | Energy Related Derivative [Member]

Income Statement Impact of Derivative Activity [Abstract]

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

^[3]

(14)

Natural Gas Expenses [Member] | Fair Value Hedging [Member] | CERC Corp [Member] | Energy Related Derivative [Member]

Income Statement Impact of Derivative Activity [Abstract]

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

^[13]

(14)

(13)

Amounts excluded from effectiveness testing recognized in earnings immediately

^[13]

(213)

(149)

(67)

Natural Gas Expenses [Member] | Fair Value Hedging [Member] | CERC Corp [Member] | Designated as Hedging Instrument [Member] | Energy Related Derivative [Member]

Income Statement Impact of Derivative Activity [Abstract]

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

^[13]

(14)

Gains (Losses) in Other Income (Expense) [Member] | Interest Rate Contract [Member]

Income Statement Impact of Derivative Activity [Abstract]

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

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

Income Statement Impact of Derivative Activity [Abstract]

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

$ (292)

$ (232)

$ 49

[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 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]	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 the years ended December 31, 2019, 2018 and 2017, respectively.
[4]	The amounts reflected in the table above were not impacted by collateral netting.
[5]	End users are comprised primarily of customers who have contracted to fix the price of a portion of their physical gas requirements for future periods.
[6]	“Investment grade” is primarily determined using publicly available credit ratings and considers credit support (including parent company guarantees) and collateral (including cash and standby letters of credit). For unrated counterparties, CERC determines a synthetic credit rating by performing financial statement analysis and consider contractual rights and restrictions and collateral.
[7]	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.
[8]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.
[9]	Natural gas contracts are presented on a net basis in CenterPoint Energy’s 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 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
[10]	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.
[11]	Natural gas contracts are presented on a net basis in CERC’s 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 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.
[12]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.
[13]	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 the years ended December 31, 2019, 2018 and 2017, respectively.

Stock-Based Incentive Compensation Plans and Employee Benefit Plans Pension and Postretirement Benefits (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Changes in plan assets and benefit obligations recognized in other comprehensive income

$ (754)

$ (796)

$ (754)

$ (796)

^[1]

(8)

(6)

Other Postretirement Benefits Plan [Member]

^[1]

(1)

^[2]

$ 2

^[3]

^[3]

(5)

^[3]

(5)

Assumptions used to determine net periodic benefit (income) cost

$ 8

$ 5

$ 8

3.20%

3.60%

4.15%

3.95%

^[4]

4.60%

^[4]

4.60%

4.55%

4.50%

$ 331

$ 386

^[2]

$ 2

^[3]

(26)

(25)

^[5]

(21)

(52)

$ 356

$ 331

356

331

386

114

120

(26)

(25)

(2)

128

114

128

114

$ 120

(228)

(217)

(228)

(217)

(8)

(6)

(8)

(6)

(220)

(211)

(220)

(211)

$ (228)

$ (217)

$ (228)

$ (217)

3.25%

^[6]

4.35%

^[6]

3.25%

^[6]

4.35%

^[6]

3.60%

Prescription drug cost trend rate assumed for the next year - Pre-65

3.95%

^[4]

4.60%

^[4]

4.60%

4.55%

4.50%

8.00%

9.20%

Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)

4.50%

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Amounts recognized in accumulated other comprehensive loss

Unrecognized actuarial loss (gain)

$ (16)

$ (7)

$ (16)

$ (7)

Unrecognized prior service cost

Deferred Tax Benefit On Accumulated Other Comprehensive Income

Net amount recognized in accumulated other comprehensive loss (gain)

$ (9)

$ (2)

(9)

(2)

Changes in plan assets and benefit obligations recognized in other comprehensive income

Net loss (gain)

(8)

Total recognized in comprehensive income

(7)

Total expense recognized in net periodic cost and other comprehensive income

Pension Plan [Member]

Assumptions used to determine net periodic benefit (income) cost

$ 93

$ 61

$ 95

4.35%

3.65%

4.15%

Rate of increase in compensation levels

5.75%

^[7]

6.00%

^[7]

6.00%

4.60%

4.45%

4.50%

$ 2,013

$ 2,225

332

(244)

(201)

^[8]

216

(127)

Curtailment

(1)

$ 2,453

$ 2,013

2,453

2,013

$ 2,225

Plan assets assumed in Merger

1,516

1,801

286

109

(244)

(201)

338

(153)

2,005

1,516

2,005

1,516

$ 1,801

(448)

(497)

(448)

(497)

(8)

(7)

(8)

(7)

(440)

(490)

(440)

(490)

$ (448)

$ (497)

$ (448)

$ (497)

3.20%

^[9]

4.35%

^[9]

3.20%

^[9]

4.35%

^[9]

3.65%

Rate of increase in compensation levels

5.75%

^[7]

6.00%

^[7]

6.00%

4.95%

4.60%

4.95%

4.60%

Interest crediting rate

3.25%

3.75%

3.25%

3.75%

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Amounts recognized in accumulated other comprehensive loss

Unrecognized actuarial loss (gain)

$ 105

$ 109

$ 105

$ 109

Unrecognized prior service cost

Deferred Tax Benefit On Accumulated Other Comprehensive Income

Net amount recognized in accumulated other comprehensive loss (gain)

105

110

105

110

Changes in plan assets and benefit obligations recognized in other comprehensive income

Net loss (gain)

(8)

Total recognized in comprehensive income

(1)

(5)

Total expense recognized in net periodic cost and other comprehensive income

Pension benefits that have accumulated benefit obligations in excess of plan assets

Accumulated benefit obligation

2,352

1,930

2,352

1,930

Projected benefit obligation

2,385

1,952

2,385

1,952

Fair value of plan assets

2,005

1,516

2,005

1,516

Accumulated benefit obligation for all defined benefit pension plans

2,420

1,991

2,420

1,991

Non-qualified Pension Plan [Member]

Pension benefits that have accumulated benefit obligations in excess of plan assets

Accumulated benefit obligation

Projected benefit obligation

Fair value of plan assets

$ 0

Minimum [Member] | Other Postretirement Benefits Plan [Member]

Health care cost trend rate assumed for the next year

5.50%

5.95%

5.50%

5.95%

Year that the cost trend rates reach the ultimate trend rate

2028

2026

Maximum [Member] | Other Postretirement Benefits Plan [Member]

Health care cost trend rate assumed for the next year

5.75%

28.60%

5.75%

28.60%

Year that the cost trend rates reach the ultimate trend rate

2029

2027

Changes in plan assets and benefit obligations recognized in other comprehensive income

$ (83)

$ (93)

$ (83)

$ (93)

^[1]

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

^[1]

(1)

^[2]

$ 1

^[3]

^[3]

(1)

^[3]

Assumptions used to determine net periodic benefit (income) cost

$ 6

$ 5

$ 6

3.20%

3.60%

4.15%

3.35%

^[4]

4.15%

^[4]

4.15%

3.85%

3.60%

$ 110

$ 109

^[2]

$ 1

^[3]

(8)

(9)

^[5]

(15)

(1)

$ 102

$ 110

102

110

109

(8)

(9)

$ 26

(75)

(85)

(75)

(85)

(3)

(72)

(82)

(72)

(82)

$ (75)

$ (85)

$ (75)

$ (85)

3.25%

^[6]

4.35%

^[6]

3.25%

^[6]

4.35%

^[6]

3.60%

Prescription drug cost trend rate assumed for the next year - Pre-65

3.35%

^[4]

4.15%

^[4]

4.15%

3.85%

3.60%

8.00%

9.20%

Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)

4.50%

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Amounts recognized in accumulated other comprehensive loss

Unrecognized actuarial loss (gain)

$ (12)

$ (3)

$ (12)

$ (3)

Unrecognized prior service cost

Deferred Tax Benefit On Accumulated Other Comprehensive Income

(9)

Net amount recognized in accumulated other comprehensive loss (gain)

$ (5)

$ (7)

(5)

$ (7)

Changes in plan assets and benefit obligations recognized in other comprehensive income

Net loss (gain)

(6)

Total recognized in comprehensive income

(1)

(7)

Total expense recognized in net periodic cost and other comprehensive income

(1)

CERC Corp [Member] | Non-qualified Pension Plan [Member]

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

$ 0

Health care cost trend rate assumed for the next year

5.50%

5.95%

5.50%

5.95%

Year that the cost trend rates reach the ultimate trend rate

2028

2026

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

Health care cost trend rate assumed for the next year

5.75%

28.60%

5.75%

28.60%

Year that the cost trend rates reach the ultimate trend rate

2029

2027

Changes in plan assets and benefit obligations recognized in other comprehensive income

$ (75)

$ (91)

$ (75)

$ (91)

^[1]

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

^[1]

^[2]

$ 1

^[3]

^[3]

(4)

^[3]

(6)

(5)

(6)

Assumptions used to determine net periodic benefit (income) cost

$ (2)

$ (1)

$ 0

3.20%

3.60%

4.15%

4.05%

^[4]

4.70%

^[4]

4.70%

4.75%

$ 166

$ 225

^[2]

$ 1

^[3]

(13)

^[5]

(4)

(56)

$ 162

$ 166

162

166

225

(13)

(2)

101

$ 93

(61)

(77)

(61)

(77)

(61)

(77)

(61)

(77)

$ (61)

$ (77)

$ (61)

$ (77)

3.25%

^[6]

4.35%

^[6]

3.25%

^[6]

4.35%

^[6]

3.60%

Prescription drug cost trend rate assumed for the next year - Pre-65

4.05%

^[4]

4.70%

^[4]

4.70%

4.75%

8.00%

9.20%

Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)

4.50%

Annualized individual discount rates based on time period, minimum

6 months

Annualized individual discount rates based on time period, maximum

99 years

Houston Electric [Member] | Non-qualified Pension Plan [Member]

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

$ 0

Health care cost trend rate assumed for the next year

5.50%

5.95%

5.50%

5.95%

Year that the cost trend rates reach the ultimate trend rate

2028

2026

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

Health care cost trend rate assumed for the next year

5.75%

28.60%

5.75%

28.60%

Year that the cost trend rates reach the ultimate trend rate

2029

2027

Operation And Maintenance Expense [Member] | Pension Plan [Member]

^[10]

$ 40

$ 37

$ 36

Other Nonoperating Income (Expense) [Member] | Pension Plan [Member]

^[10]

^[11]

^[11]

(105)

(107)

(97)

Amortization of net loss (2)

^[11]

^[11]

Settlement cost (2) (3)

^[11]

^[12]

Curtailment gain (2) (4)

^[11]

(1)

^[13]

Derivative Instruments and Hedging Activities Disclosure [Abstract]

^[11]

$ 96

$ 79

$ 89

[1]	Amounts are included in the computation of net periodic cost and are reflected in Other, net in each of the Registrants’ respective Statements of Consolidated Income.
[2]	Amounts presented in the table above are included in Operation and maintenance expense in each of the Registrants’ respective Statements of Consolidated Income, net of regulatory deferrals and amounts capitalized.
[3]	Amounts presented in the table above are included in Other, net in each of the Registrants’ respective Statements of Consolidated Income, net of regulatory deferrals.
[4]	The expected rate of return assumption was developed using the targeted asset allocation of the plans and the expected return for each asset class.
[5]	Significant sources of gain for 2019 include favorable cost trend rates and benefit claims experience in addition to the change in mortality projection scale from MP2018 to MP2019. Significant sources of gain for 2018 include the increase in the discount rate from 3.60% to 4.35%, favorable benefit claims experience and cost trend rates in addition to the change in mortality projection scale from MP2017 to MP2018.
[6]	The discount rate assumption was determined by matching the projected cash flows of the plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.
[7]	The expected rate of return assumption was developed using the targeted asset allocation of CenterPoint Energy’s plans and the expected return for each asset class.
[8]	Significant sources of loss for 2019 include the decrease in discount rate from 4.35% to 3.20%. Significant sources of gain for 2018 include the increase in discount rate from 3.65% to 4.35% and the mortality projection scale change from MP2017 to MP2018.
[9]	The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.
[10]	Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income, net of regulatory deferrals and amounts capitalized.
[11]	Amounts presented in the table above are included in Other, net in CenterPoint Energy’s Statements of Consolidated Income, net of regulatory deferrals.
[12]	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. In 2019, CenterPoint Energy recognized a non-cash settlement cost due to lump sum settlement payments.
[13]	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 2019, CenterPoint Energy recognized a pension curtailment gain related to employees who were terminated after the Merger closed.

Derivative Instruments

12 Months Ended

Dec. 31, 2019

Derivative Instruments [Text Block]

Derivative Instruments

(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.

On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

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 13.

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



	December 31, 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 summarizes CenterPoint Energy’s and CERC’s weather hedge gain (loss) activity:

CenterPoint Energy



				Year Ended December 31,
Texas Operations	Winter Season	Bilateral Cap		2019		2018			2017
		(in millions)
NGD	2019 – 2020	$	8	$	2	$	—		$	—
NGD	2018 – 2019	9		—		—			—
NGD	2017 – 2018	8		—		(2		)	—
Electric operations	2019 – 2020	7		3		—			—
Electric operations	2018 – 2019	8		3		—			—
Electric operations	2017 – 2018	9		—		(2		)	—
Electric operations	2016 – 2017	9		—		—			(1		)
Total CenterPoint Energy (1)				$	8	$	(4	)	$	(1	)

CERC



				Year Ended December 31,
Texas Operations	Winter Season	Bilateral Cap		2019		2018			2017
		(in millions)
NGD	2019 – 2020	$	8	$	2	$	—		$	—
NGD	2018 – 2019	9		—		—			—
NGD	2017 – 2018	8		—		(2		)	—
Total CERC (1)				$	2	$	(2	)	$	—


(1)	Weather hedge gains (losses) are recorded in Revenues in the 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 as of December 31, 2019 and 2018, while the last two tables provide a breakdown of the related income statement impacts for the years ending December 31, 2019, 2018 and 2017.

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy



		December 31, 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	12		—		1		7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	139		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	58		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	73		184		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	10		54		16		25
Interest rate derivatives	Other Liabilities	—		10		—		—
Indexed debt securities derivative	Current Liabilities	—		893		—		601
Total CenterPoint Energy		$	292	$	1,144	$	220	$	833


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 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 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 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



		December 31, 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



		December 31, 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	$	12	$	—	$	1	$	7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	139		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	58		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	73		177		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	10		39		16		25
Total CERC		$	292	$	219	$	220	$	208


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 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 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 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)



CenterPoint Energy
		December 31, 2019					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			Carrying Amount of Hedged Assets/(Liabilities)		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	47	$	(13	)	$	57	$	1
Total CenterPoint Energy		$	47	$	(13	)	$	57	$	1



CERC
		December 31, 2019					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			Carrying Amount of Hedged Assets/(Liabilities)		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	47	$	(13	)	$	57	$	1
Total CERC		$	47	$	(13	)	$	57	$	1

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



CenterPoint Energy
	December 31, 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	$	224		$	(88	)	$	136		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	68			(10		)	58			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(187		)	136			(51		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(54		)	25			(29		)	(25		)	20			(5		)
Total CenterPoint Energy	$	51		$	63		$	114		$	12		$	19		$	31



CERC
	December 31, 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	$	224		$	(88	)	$	136		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	68			(10		)	58			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(180		)	136			(44		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(39		)	25			(14		)	(25		)	20			(5		)
Total CERC	$	73		$	63		$	136		$	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 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)



CenterPoint Energy	Year Ended December 31,
	2019			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	4,029		$	4,364		$	3,785

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(14		)	(13		)	14
Derivatives designated as hedging instruments	14			13			(14		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(213		)	(149		)	(67		)


(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 the years ended December 31, 2019, 2018 and 2017, respectively.



CERC	Year Ended December 31,
	2019			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	3,503		$	4,364		$	3,785

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(14		)	(13		)	14
Derivatives designated as hedging instruments	14			13			(14		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(213		)	(149		)	(67		)


(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 the years ended December 31, 2019, 2018 and 2017, respectively.

CenterPoint Energy



		Year Ended December 31,
	Income Statement Location	2019			2018			2017
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (Losses) in Non-utility revenues	$	214		$	107		$	211
Indexed debt securities derivative	Gain (loss) on indexed debt securities	(292		)	(232		)	49
Interest rate derivatives	Gains in Other Income (Expense)	—			2			—
Total CenterPoint Energy		$	(78	)	$	(123	)	$	260

CERC



		Year Ended December 31,
	Income Statement Location	2019		2018		2017
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (Losses) in Non-utility revenues	$	214	$	107	$	211
Total CERC		$	214	$	107	$	211

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.



	December 31, 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		—		—

(d) Credit Quality of Counterparties (CenterPoint Energy and CERC)

In addition to the risk associated with price movements, credit risk is also inherent in CenterPoint Energy’s and CERC’s non-trading derivative activities. Credit risk relates to the risk of loss resulting from non-performance of contractual obligations by a counterparty. The following tables show the composition of counterparties to the non-trading derivative assets:

CenterPoint Energy



	December 31, 2019				December 31, 2018
	Investment Grade (1)		Total (3)		Investment Grade (1)		Total (3)
	(in millions)
Energy marketers	$	4	$	16	$	11	$	24
End users (2)	27		178		30		114
Total CenterPoint Energy	$	31	$	194	$	41	$	138

CERC



	December 31, 2019				December 31, 2018
	Investment Grade (1)		Total (3)		Investment Grade (1)		Total (3)
	(in millions)
Energy marketers	$	4	$	16	$	11	$	24
End users (2)	27		178		30		114
Total CERC	$	31	$	194	$	41	$	138


(1)	“Investment grade” is primarily determined using publicly available credit ratings and considers credit support (including parent company guarantees) and collateral (including cash and standby letters of credit). For unrated counterparties, CERC determines a synthetic credit rating by performing financial statement analysis and consider contractual rights and restrictions and collateral.


(2)	End users are comprised primarily of customers who have contracted to fix the price of a portion of their physical gas requirements for future periods.

(3)

The amounts reflected in the table above were not impacted by collateral netting.

Summary of Significant Accounting Policies (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Provision for doubtful accounts

$ 162

$ 16

$ 14

Interest Expense [Member]

Interest and AFUDC debt (1)

^[1]

Other Income (Expense) [Member]

AFUDC equity (2)

^[2]

Provision for doubtful accounts

Houston Electric [Member] | Interest Expense [Member]

Interest and AFUDC debt (1)

^[1]

Houston Electric [Member] | Other Income (Expense) [Member]

AFUDC equity (2)

^[2]

Provision for doubtful accounts

CERC Corp [Member] | Interest Expense [Member]

Interest and AFUDC debt (1)

^[1]

CERC Corp [Member] | Other Income (Expense) [Member]

Quarterly Financial Information Disclosure [Abstract]

AFUDC equity (2)

^[2]

$ 3

$ 2

$ 1

[1]	Included in Interest and other finance charges on the Registrants’ respective Statements of Consolidated Income.
[2]	Included in Other Income (Expense) on the Registrants’ respective Statements of Consolidated Income.

Unaudited Quarterly Information

12 Months Ended

Dec. 31, 2019

Unaudited Quarterly Information [Text Block]

Unaudited Quarterly Information

Summarized quarterly financial data is as follows:



	Year Ended December 31, 2019
	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
	(in millions, except per share amounts)
CenterPoint Energy
Revenues	$	3,531	$	2,798	$	2,742		$	3,230
Operating income	245		287		392			302
Income available to common shareholders	140		165		241			128
Basic earnings per common share (1)	0.28		0.33		0.48			0.25
Diluted earnings per common share (1)	0.28		0.33		0.47			0.25
Houston Electric
Revenues	686		765		859			680
Operating income	81		169		269			99
Net income	27		100		185			44
CERC
Revenues	2,368		1,342		1,126			1,734
Operating income	196		58		23			73
Net income (loss)	138		28		(7		)	53



	Year Ended December 31, 2018
	First Quarter		Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per share amounts)
CenterPoint Energy
Revenues	$	3,155	$	2,186		$	2,212		$	3,036
Operating income	251		187			226			167
Income (loss) available to common shareholders	165		(75		)	153			90
Basic earnings (loss) per common share (1)	0.38		(0.17		)	0.35			0.18
Diluted earnings (loss) per common share (1)	0.38		(0.17		)	0.35			0.18
Houston Electric
Revenues	755		854			897			728
Operating income	119		181			227			98
Net income	52		101			143			40
CERC (2)
Revenues	2,400		1,328			1,312			2,303
Operating income (loss)	131		22			(7		)	76
Income (loss) from continuing operations	78		(8		)	(35		)	35
Income (loss) from discontinued operations	52		44			44			(2		)
Net income	130		36			9			33


(1)	Quarterly earnings (loss) per common share are based on the weighted average number of shares outstanding during the quarter, and the sum of the quarters may not equal annual earnings (loss) per common share.

(2)

Amounts have been recast to reflect discontinued operations in all periods presented.

STATEMENTS OF CONSOLIDATED SHAREHOLDERS' EQUITY - USD ($)
$ in Millions

Total

Series A Preferred Stock [Member]

Series B Preferred Stock [Member]

Preferred Stock [Member]

Series A Preferred Stock [Member]

Preferred Stock [Member]

Series B Preferred Stock [Member]

Common Stock [Member]

Additional Paid-in Capital [Member]

Common Stock [Member]

Retained Earnings [Member]

Series A Preferred Stock [Member]

Retained Earnings [Member]

Series B Preferred Stock [Member]

AOCI Attributable to Parent [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]

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]

Balance, beginning of year at Dec. 31, 2016

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Balance, end of year at Dec. 31, 2017

Balance, beginning of year at Dec. 31, 2016

431,000,000

1,000

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Balance, end of year at Dec. 31, 2017

431,000,000

1,000

Balance, beginning of year at Dec. 31, 2016

$ 0

$ 4

$ 4,195

$ (668)

$ (71)

$ 0

$ 1,696

$ 420

$ 1

$ 0

$ 2,489

$ 430

$ 3

Increase (Decrease) in Stockholders' Equity [Roll Forward]

$ 0

Capital distribution associated with the Internal Spin

$ 0

Common Stock dividends declared ($0.8625, $1.1200 and $1.3475 per share, respectively)

1,792

433

745

(581)

Preferred stock dividends declared

$ 0

Dividend to parent

(180)

(601)

Other comprehensive income (loss)

(1)

Balance, end of year at Dec. 31, 2017

$ 4,688

$ 0

$ 4

4,209

543

(68)

2,369

$ 0

1,696

673

3,108

$ 0

2,528

574

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Adoption of ASU 2018-02 | Adjustments for New Accounting Principle, Early Adoption [Member]

Balance, end of year at Dec. 31, 2018

1,000,000

70,000,000

800,000

977,500

2,000,000

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Balance, end of year at Dec. 31, 2018

501,197,784

501,000,000

1,000

Increase (Decrease) in Stockholders' Equity [Roll Forward]

$ 0

$ 790

$ 950

1,844

Capital distribution associated with the Internal Spin

200

960

$ 0

(1,473)

^[1]

1,473

Common Stock dividends declared ($0.8625, $1.1200 and $1.3475 per share, respectively)

368

336

208

(523)

Preferred stock dividends declared

$ (26)

$ (28)

(26)

(28)

Dividend to parent

(209)

(360)

Other comprehensive income (loss)

(25)

(14)

Balance, end of year at Dec. 31, 2018

$ 8,058

$ 1,740

$ 5

6,072

349

(108)

2,682

$ 0

1,896

800

(14)

2,443

$ 0

2,015

423

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Adoption of ASU 2018-02 | Adjustments for New Accounting Principle, Early Adoption [Member]

(15)

(1)

Balance, end of year at Dec. 31, 2019

800,000

977,500

2,000,000

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,000,000

Balance, end of year at Dec. 31, 2019

502,242,061

502,000,000

1,000

Increase (Decrease) in Stockholders' Equity [Roll Forward]

$ 0

$ 0

Capital distribution associated with the Internal Spin

590

129

$ 0

(28)

^[1],[2]

Common Stock dividends declared ($0.8625, $1.1200 and $1.3475 per share, respectively)

791

356

212

(433)

Preferred stock dividends declared

$ (24)

$ (51)

$ (24)

$ (51)

Dividend to parent

(376)

(120)

Other comprehensive income (loss)

(1)

Balance, end of year at Dec. 31, 2019

$ 8,359

$ 1,740

$ 5

$ 6,080

632

(98)

$ 3,251

$ 0

$ 2,486

$ 780

$ (15)

$ 2,641

$ 0

$ 2,116

515

Balance, end of year (Adjustments for New Accounting Principle, Early Adoption [Member]) at Dec. 31, 2019

2,641

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Adoption of ASU 2018-02 | Adjustments for New Accounting Principle, Early Adoption [Member]

$ 0

[1]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.
[2]	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.

Background

12 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Background [Text Block]

Background

General. This combined Form 10-K 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 Note 14 to the Registrants’ 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-K are the Financial Statements of CenterPoint Energy, Houston Electric and CERC, which are referred to collectively as the Registrants. The Combined Notes to the Consolidated Financial Statements apply to all Registrants and specific references to Houston Electric and CERC herein also pertain to CenterPoint Energy, unless otherwise indicated.

Background. CenterPoint Energy, Inc. is a public utility holding company 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 December 31, 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 Corp. (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.

For a description of CenterPoint Energy’s and CERC’s reportable segments, see Note 19. Houston Electric consists of a single reportable segment, Houston Electric T&D.

As of December 31, 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.

Additionally, on February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

Background (Details)
$ in Millions

12 Months Ended

Feb. 03, 2020

USD ($)

Feb. 01, 2019

USD ($)

Dec. 31, 2019

USD ($)

state

Dec. 31, 2018

Cash paid to acquire Vectren | $

$ 6,000

$ 5,982

Ownership percentage of equity method investment

^[1],[2]

53.70%

54.00%

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

Preferred units held | shares

14,520,000

Enable GP, LLC [Member]

50.00%

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

40.00%

Number of states in which entity operates | state

Number of states in which entity operates | state

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

^[3],[4]

50.00%

Subsequent Event [Member] | Infrastructure Services [Member]

^[4],[5]

40.00%

Sales price of outstanding equity interests | $

$ 850

[1]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[2]	Prior to the Internal Spin completed in September 2018, CenterPoint Energy’s investment in Enable’s common units, excluding the Enable Series A Preferred Units held directly by CenterPoint Energy, was held indirectly through CERC.
[3]	As of December 31, 2019, 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.

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions																12 Months Ended
	Feb. 24, 2020	Feb. 07, 2020	Feb. 03, 2020	Oct. 17, 2019	Jul. 31, 2019	Apr. 25, 2019	Dec. 12, 2018	Oct. 23, 2018	Jul. 26, 2018	Apr. 26, 2018	Dec. 13, 2017	Oct. 25, 2017	Jul. 27, 2017	Apr. 27, 2017	Jan. 05, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsequent Event [Line Items]
Deferred Tax Liabilities, Net, Noncurrent																$ 3,928	$ 3,239
Common stock dividends declared per share																$ 0.86	$ 1.1200	$ 1.35
Expected cash distribution on Enable Common Units																$ 261	$ 267	$ 0
Series A Preferred Units [Member] \| Subsequent Event [Member] \| Enable Midstream Partners [Member]
Subsequent Event [Line Items]
Declaration Date		Feb. 07, 2020
Record Date		Feb. 07, 2020
Payment Date		Feb. 14, 2020
Distributions Declared, Per Unit		$ 0.6250
Expected cash distribution on Enable's Series A Preferred Units		$ 9
Common Units [Member] \| Subsequent Event [Member] \| Enable Midstream Partners [Member]
Subsequent Event [Line Items]
Declaration Date		Feb. 07, 2020
Record Date		Feb. 18, 2020
Payment Date		Feb. 25, 2020
Distributions Declared, Per Unit		$ 0.3305
Expected cash distribution on Enable Common Units		$ 77
Common Stock [Member]
Subsequent Event [Line Items]
Declaration Date				Oct. 17, 2019	Jul. 31, 2019	Apr. 25, 2019	Dec. 12, 2018	Oct. 23, 2018	Jul. 26, 2018	Apr. 26, 2018	Dec. 13, 2017	Oct. 25, 2017	Jul. 27, 2017	Apr. 27, 2017	Jan. 05, 2017
Record Date				Nov. 21, 2019	Aug. 15, 2019	May 16, 2019	Feb. 21, 2019	Nov. 15, 2018	Aug. 16, 2018	May 17, 2018	Feb. 15, 2018	Nov. 16, 2017	Aug. 16, 2017	May 16, 2017	Feb. 16, 2017
Payment Date				Dec. 12, 2019	Sep. 12, 2019	Jun. 13, 2019	Mar. 14, 2019	Dec. 13, 2018	Sep. 13, 2018	Jun. 14, 2018	Mar. 08, 2018	Dec. 08, 2017	Sep. 08, 2017	Jun. 09, 2017	Mar. 10, 2017
Common stock dividends declared per share				$ 0.2875	$ 0.2875	$ 0.2875	$ 0.2875	$ 0.2775	$ 0.2775	$ 0.2775	$ 0.2775	$ 0.2675	$ 0.2675	$ 0.2675	$ 0.2675	$ 0.8625	$ 1.1200	$ 1.3475
Common Stock [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Declaration Date			Feb. 03, 2020
Record Date			Feb. 20, 2020
Payment Date			Mar. 12, 2020
Common stock dividends declared per share			$ 0.2900
Series A Preferred Stock [Member]
Subsequent Event [Line Items]
Declaration Date					Jul. 31, 2019		Dec. 12, 2018
Record Date					Aug. 15, 2019		Feb. 15, 2019
Payment Date					Sep. 03, 2019		Mar. 01, 2019
Preferred stock dividends declared per share					$ 30.6250		$ 32.1563									30.6250	32.1563	0.0000
Series A Preferred Stock [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Declaration Date			Feb. 03, 2020
Record Date			Feb. 14, 2020
Payment Date			Mar. 02, 2020
Preferred stock dividends declared per share			$ 30.6250
Series B Preferred Stock [Member]
Subsequent Event [Line Items]
Declaration Date				Oct. 17, 2019	Jul. 31, 2019	Apr. 25, 2019	Dec. 12, 2018	Oct. 23, 2018
Record Date				Nov. 15, 2019	Aug. 15, 2019	May 15, 2019	Feb. 15, 2019	Nov. 15, 2018
Payment Date				Dec. 02, 2019	Sep. 03, 2019	Jun. 03, 2019	Mar. 01, 2019	Dec. 01, 2018
Preferred stock dividends declared per share				$ 17.5000	$ 17.5000	$ 17.5000	$ 17.5000	$ 11.6667								$ 52.5000	$ 29.1667	$ 0.0000
Series B Preferred Stock [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Declaration Date			Feb. 03, 2020
Record Date			Feb. 14, 2020
Payment Date			Mar. 02, 2020
Preferred stock dividends declared per share			$ 17.5000
Infrastructure Services [Member]
Subsequent Event [Line Items]
Deferred Tax Liabilities, Net, Noncurrent																$ 123
Infrastructure Services [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Sales price of outstanding equity interests			$ 850
Energy Services [Member]
Subsequent Event [Line Items]
Deferred Tax Liabilities, Net, Noncurrent																25
Energy Services [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Sales price of outstanding equity interests	$ 400
CERC Corp [Member]
Subsequent Event [Line Items]
Deferred Tax Liabilities, Net, Noncurrent																470	$ 406
CERC Corp [Member] \| Energy Services [Member]
Subsequent Event [Line Items]
Deferred Tax Liabilities, Net, Noncurrent																$ 25
CERC Corp [Member] \| Energy Services [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Sales price of outstanding equity interests	$ 400

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Tables)

12 Months Ended

Dec. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

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



	As of December 31,
	2019				2018
	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)
CenterPoint Energy (3)	53.7	%	233,856,623	14,520,000	54.0	%	233,856,623	14,520,000
OGE	25.5	%	110,982,805	—	25.6	%	110,982,805	—
Public unitholders	20.8	%	90,361,937	—	20.4	%	88,392,983	—
Total Units Outstanding	100.0	%	435,201,365	14,520,000	100.0	%	433,232,411	14,520,000


(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 Consolidated Balance Sheets, was $363 million as of both December 31, 2019 and 2018. No

impairment charges or adjustment to carrying value were made as no observable price changes were identified in the current or prior reporting periods.

(3)

Prior to the Internal Spin completed in September 2018, CenterPoint Energy’s investment in Enable’s common units, excluding the Enable Series A Preferred Units held directly by CenterPoint Energy, was held indirectly through CERC.

Interests Held in Enable GP (CenterPoint Energy):

CenterPoint Energy and OGE held the following interests in Enable GP as of both December 31, 2019 and 2018:



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


(1)	As of December 31, 2019, 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



	Year Ended December 31,
	2019				2018				2017
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	1.2970	$	303	$	1.2720	$	297	$	1.2720	$	297
Enable Series A Preferred Units	2.5000		36		2.5000		36		2.5000		36
Total CenterPoint Energy			$	339			$	333			$	333

CERC



	Year Ended December 31,
	2018				2017
	Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)
Enable common units (1)	$	0.9540	$	223	$	1.2720	$	297
Total CERC			223				297


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

Transactions with Enable (CenterPoint Energy and CERC):



	Year Ended December 31,
	2019		2018		2017
CenterPoint Energy	(in millions)
Natural gas expenses, including transportation and storage costs (1)	$	120	$	122	$	115
Reimbursement of support services (2)	—		4		4
CERC
Natural gas expenses, including transportation and storage costs (1)	120		122		115
Reimbursement of support services (2)	—		4		4


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


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



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

CERC’s continuing involvement with Enable subsequent to the Internal Spin is limited to its natural gas purchases from Enable.

Summarized consolidated income (loss) information for Enable is as follows:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
Operating revenues	$	2,960		$	3,431		$	2,803
Cost of sales, excluding depreciation and amortization	1,279			1,819			1,381
Depreciation and amortization	433			398			366
Operating income	569			648			528
Goodwill impairment	86			—			—
Net income attributable to Enable common units	360			485			400
Reconciliation of Equity in Earnings (Losses), net:
CenterPoint Energy’s interest	$	193		$	262		$	216
Basis difference amortization (1)	47			47			49
Loss on dilution, net of proportional basis difference recognition	(11		)	(2		)	—
CenterPoint Energy’s equity in earnings, net	$	229		$	307		$	265


(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 consolidated balance sheet information for Enable is as follows:



	December 31,
	2019			2018
	(in millions)
Current assets	$	389		$	449
Non-current assets	11,877			11,995
Current liabilities	780			1,615
Non-current liabilities	4,077			3,211
Non-controlling interest	37			38
Preferred equity	362			362
Accumulated other comprehensive loss	(3		)	—
Enable partners’ equity	7,013			7,218
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,767		$	3,896
CenterPoint Energy’s basis difference	(1,361		)	(1,414		)
CenterPoint Energy’s equity method investment in Enable	$	2,406		$	2,482

Investment in Unconsolidated Affiliates (CenterPoint Energy):



	December 31, 2019		December 31, 2018
	(in millions)
Enable	$	2,406	$	2,482
Other (1)	2		—
Total	$	2,408	$	2,482


(1)	Represents the fair value of non-utility equity investments acquired in the Merger.

Equity in Earnings of Unconsolidated Affiliates, net (CenterPoint Energy):



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Enable (1)	$	229	$	307	$	265
Other	1		—		—
Total	$	230	$	307	$	265


(1)	Equity earnings for the year ended December 31, 2019 includes CenterPoint Energy’s share of Enable’s $86 million goodwill impairment recorded in the fourth quarter of 2019.

Disposal Groups, Including Discontinued Operations [Table Text Block]



	Year Ended December 31,
	2018		2017
	(in millions)
Equity in earnings of unconsolidated affiliate, net	$	184	$	265
Income tax expense	46		104
Income from discontinued operations, net of tax	$	138	$	161

Reportable Segments [Text Block]

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

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
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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 5: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 8: 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 11: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 12: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 13: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
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+ Details

Reportable Segments

12 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

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 December 31, 2019, reportable segments by Registrant are 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


•	CenterPoint Energy’s and Houston Electric’s Houston Electric T&D reportable segment consists of electric transmission and distribution services in the Texas Gulf Coast area.


•	CenterPoint Energy’s 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.


•	CenterPoint Energy’s and CERC’s Energy Services reportable segment consists of non-rate regulated natural gas sales and services operations.


•	CenterPoint Energy’s Infrastructure Services reportable segment consists of underground pipeline construction and repair services.


•	CenterPoint Energy’s 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.

On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Purchase Agreement to sell its Infrastructure Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23 to the consolidated financial statements.

Expenditures for long-lived assets include property, plant and equipment. Intersegment sales are eliminated in consolidation, except as described in Note 2(b).

Financial data for reportable segments and products and services are as follows:

CenterPoint Energy



	Revenues from External Customers			Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets				Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2019:
Houston Electric T&D	$	2,996	(1)	$	—		$	648	$	624		$	11,264			$	1,033
Indiana Electric Integrated	523			—			91		90			3,168				183
Natural Gas Distribution	3,643			40			417		408			13,903				1,098
Energy Services	3,653			129			16		32			1,301				12
Infrastructure Services	1,186		(2)	4			50		95			1,077				67
Midstream Investments (3)	—			—			—		—			2,473				—
Corporate and Other	300			—			65		(23		)	4,784			(4)	194
Eliminations	—			(173		)	—		—			(2,531		)		—
Consolidated	$	12,301		$	—		$	1,287	$	1,226		$	35,439			$	2,587
Reconciling items																(81		)
Capital expenditures per Statements of Consolidated Cash Flows																$	2,506

As of and for the year ended December 31, 2018:
Houston Electric T&D	$	3,232	(1)	$	—		$	917	$	623		$	10,509			$	952
Natural Gas Distribution	2,931			36			277		266			6,956				638
Energy Services	4,411			110			16		(47		)	1,558				20
Midstream Investments (3)	—			—			—		—			2,482				—
Corporate and Other	15			—			33		(11		)	6,156			(4)	110
Eliminations	—			(146		)	—		—			(652		)		—
Consolidated	$	10,589		$	—		$	1,243	$	831		$	27,009			$	1,720
Reconciling items																(69		)
Capital expenditures per Statements of Consolidated Cash Flows																$	1,651

As of and for the year ended December 31, 2017:
Houston Electric T&D	$	2,997	(1)	$	—		$	724	$	636		$	10,292			$	924
Natural Gas Distribution	2,606			33			260		348			6,608				523
Energy Services	3,997			52			19		126			1,521				11
Midstream Investments (3)	—			—			—		—			2,472				—
Corporate and Other	14			—			33		26			2,497			(4)	36
Eliminations	—			(85		)	—		—			(654		)		—
Consolidated	$	9,614		$	—		$	1,036	$	1,136		$	22,736			$	1,494
Reconciling items																(68		)
Capital expenditures per Statements of Consolidated Cash Flows																$	1,426


(1)	CenterPoint Energy’s Houston Electric T&D’s revenues from major customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229


(2)	Includes revenues not eliminated in consolidation for pipeline construction and repair services of $162 million capitalized by CenterPoint Energy’s NGD for the 11 months ended December 31, 2019. See Note 2(b).


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



	Year Ended December 31,
	2019		2018		2016
	(in millions)
Enable	$	229	$	307	$	265


(4)	Total assets included pension and other postemployment-related regulatory assets of $584 million, $665 million and $600 million as of December 31, 2019, 2018 and 2017, respectively. 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.

Houston Electric

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

included.


(1)	Houston Electric’s revenues from major external customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229

CERC



	Revenues from External Customers		Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets (1)			Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2019:
Natural Gas Distribution	$	2,911	$	40		$	289	$	316		$	7,497		$	773
Energy Services	3,654		128			16		32			1,301			12
Other Operations	5		—			—		2			149			—
Eliminations	—		(168		)	—		—			(508		)	—
Consolidated	$	6,570	$	—		$	305	$	350		$	8,439		$	785
Reconciling items														(9		)
Capital expenditures per Statements of Consolidated Cash Flows														$	776
As of and for the year ended December 31, 2018:
Natural Gas Distribution	$	2,931	$	36		$	277	$	266		$	6,956		$	638
Energy Services	4,411		110			16		(47		)	1,558			20
Other Operations	1		—			—		3			66			—
Eliminations	—		(146		)	—		—			(366		)	—
Consolidated	$	7,343	$	—		$	293	$	222		$	8,214		$	658
Reconciling items														(25		)
Capital expenditures per Statements of Consolidated Cash Flows														$	633



	Revenues from External Customers		Net Intersegment Revenues			Depreciation and Amortization		Operating Income (Loss)			Total Assets (1)				Expenditures for Long-Lived Assets
	(in millions)
As of and for the year ended December 31, 2017:
Natural Gas Distribution	$	2,606	$	33		$	260	$	348		$	6,608			$	523
Energy Services	3,997		52			19		126			1,521				11
Discontinued operations	—		—			—		—			2,472			(1)	—
Other Operations	—		—			—		(7		)	70				—
Eliminations	—		(85		)	—		—			(559		)		—
Consolidated	$	6,603	$	—		$	279	$	467		$	10,112			$	534
Reconciling items															(21		)
Capital expenditures per Statements of Consolidated Cash Flows															$	513


(1)	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 11.



	Year Ended December 31,
	2019						2018						2017
Revenues by Products and Services:	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Electric delivery	$	3,019	$	2,990	$	—	$	3,232	$	3,234	$	—	$	2,997	$	2,998	$	—
Retail electric sales	486		—		—		—		—		—		—		—		—
Wholesale electric sales	14		—		—		—		—		—		—		—		—
Retail gas sales	4,802		—		4,070		4,161		—		4,161		3,634		—		3,634
Wholesale gas sales	2,312		—		2,313		3,008		—		3,008		2,811		—		2,811
Gas transportation and processing	33		—		33		32		—		32		29		—		29
Infrastructure services	1,186		—		—		—		—		—		—		—		—
Energy products and services	449		—		154		156		—		142		143		—		129
Total	$	12,301	$	2,990	$	6,570	$	10,589	$	3,234	$	7,343	$	9,614	$	2,998	$	6,603

Leases (Tables)

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Lease, Cost [Table Text Block]

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



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	25	$	—	$	5
Short-term lease cost	75		23		—
Variable lease cost	1		—		1
Total lease cost	$	101	$	23	$	6

Operating Lease, Lease Income [Table Text Block]

The components of lease income were as follows:



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease income	$	4	$	2	$	1
Variable lease income	2		—		—
Total lease income	$	6	$	2	$	1

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

Supplemental balance sheet information related to leases was as follows:



	December 31, 2019
	CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	63		$	1		$	24
Total leased assets	$	63		$	1		$	24
Liabilities:
Current operating lease liability (2)	$	21		$	—		$	4
Non-current operating lease liability (3)	42			1			20
Total leased liabilities	$	63		$	1		$	24

Weighted-average remaining lease term (in years) - operating leases	5.1			5.2			7.7
Weighted-average discount rate - operating leases	3.42		%	3.52		%	3.67		%


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


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

(3)

Reported within Other liabilities in the Registrants’ respective Consolidated Balance Sheets.

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

As of December 31, 2019, maturities of operating lease liabilities were as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	22	$	1	$	6
2021	16		—		4
2022	9		—		4
2023	7		—		3
2024	3		—		2
2025 and beyond	12		—		9
Total lease payments	69		1		28
Less: Interest	6		—		4
Present value of lease liabilities	$	63	$	1	$	24

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 December 31, 2019, maturities of undiscounted operating lease payments to be received are as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	3	$	1	$	1
2021	2		—		—
2022	2		—		—
2023	2		—		—
2024	2		—		—
2025 and beyond	10		—		—
Total lease payments to be received	$	21	$	1	$	1

Other Information Related To Leases [Table Text Block]

Other information related to leases is as follows. See Note 20 for information on ROU assets obtained in exchange for operating lease liabilities:



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	$	25	$	1	$	6

Earnings Per Share (CenterPoint Energy)

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Earnings Per Share (CenterPoint Energy) [Text Block]

Earnings Per Share (CenterPoint Energy)



	For the Year Ended December 31,
	2019		2018		2017
	(in millions, except per share and share amounts)
Numerator:
Income available to common shareholders - basic (1)	$	674	$	333	$	1,792
Add back: Series B Preferred Stock dividend (2)	—		—		—
Income available to common shareholders - diluted (1)	$	674	$	333	$	1,792

Denominator:
Weighted average common shares outstanding - basic	502,050,000		448,829,000		430,964,000
Plus: Incremental shares from assumed conversions:
Restricted stock (3)	3,107,000		3,636,000		3,344,000
Series B Preferred Stock (2)	—		—		—
Weighted average common shares outstanding - diluted	505,157,000		452,465,000		434,308,000

Earnings per common share:
Basic earnings per common share	$	1.34	$	0.74	$	4.16
Diluted earnings per common share	$	1.33	$	0.74	$	4.13


(1)	Income available to common shareholders for the year ended December 31, 2019 includes net income from businesses acquired in the Merger of $190 million. See Note 4. Income available to common shareholders for the year ended December 31, 2017 includes a reduction in income tax expense of $1,113 million due to tax reform. See Note 15 for further discussion of the impacts of the TCJA.

(2)

(3)

The potentially dilutive impact from restricted stock awards applies the treasury stock method. Under this method, an increase in the average fair market value of Common Stock can result in a greater dilutive impact from these securities.

CONSOLIDATED BALANCE SHEETS - USD ($)
$ in Millions

Dec. 31, 2019

Dec. 31, 2018

Investment in marketable securities

^[1]

$ 241

$ 4,231

822

540

Accrued unbilled revenues

1,249

1,190

586

378

Natural gas and coal inventory

277

194

Materials and supplies

269

200

136

100

Taxes receivable

106

Property, Plant and Equipment, net

161

192

Total current assets

3,847

7,025

20,945

14,044

5,164

867

2,117

1,967

Investment in unconsolidated affiliates

2,408

2,482

Preferred units - unconsolidated affiliate

363

Intangible Assets, Net (Excluding Goodwill)

321

216

158

Total other assets

10,647

5,940

Current portion of VIE Securitization Bonds long-term debt

35,439

27,009

Current Liabilities:

231

458

Indexed debt, net

Current portion of other long-term debt

618

Indexed debt securities derivative

893

601

Accounts payable

1,138

1,240

Taxes accrued

241

204

Interest accrued

158

121

Dividends accrued

187

Customer deposits

125

126

Total current liabilities

414

255

3,888

3,302

Other Liabilities:

Deferred income taxes, net

3,928

3,239

Benefit obligations

754

796

3,474

2,525

VIE Securitization Bonds, net

763

402

Total other liabilities

8,948

6,967

Long-term Debt:

746

977

Other long-term debt, net

13,498

7,705

Total long-term debt, net

14,244

8,682

Commitments and Contingencies (Note 16)

Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized

Common stock

Additional paid-in capital

6,080

6,072

Retained earnings

632

349

Accumulated other comprehensive income (loss)

(98)

(108)

Total shareholders’ equity

8,359

8,058

Total Liabilities and Shareholders’ Equity

35,439

27,009

Accounts and notes receivable, net

^[2]

216

335

238

283

Accounts and notes receivable—affiliated companies

523

Accrued unbilled revenues

117

110

Materials and supplies

147

135

Taxes receivable

Property, Plant and Equipment, net

Total current assets

1,290

949

9,032

8,402

915

1,124

Total other assets

940

1,156

Current portion of VIE Securitization Bonds long-term debt

11,262

10,507

Current Liabilities:

231

458

Accounts payable

268

262

Accounts and notes payable—affiliated companies

Taxes accrued

123

115

Interest accrued

Total current liabilities

830

1,090

Other Liabilities:

Deferred income taxes, net

1,030

1,023

Benefit obligations

1,288

1,298

VIE Securitization Bonds, net

Total other liabilities

2,462

2,477

Long-term Debt:

746

977

Other long-term debt, net

3,973

3,281

Total long-term debt, net

4,719

4,258

Commitments and Contingencies (Note 16)

Additional paid-in capital

Common stock

2,486

1,896

Retained earnings

780

800

Accumulated other comprehensive income (loss)

(15)

(14)

Total shareholders’ equity

3,251

2,682

Total Liabilities and Shareholders’ Equity

11,262

10,507

Accounts and notes receivable—affiliated companies

693

894

120

Accrued unbilled revenues

257

268

Natural gas and coal inventory

202

194

Materials and supplies

136

100

Property, Plant and Equipment, net

115

Total current assets

1,415

1,770

5,836

5,226

819

867

191

181

120

132

Total other assets

1,188

1,218

Accounts and notes payable—affiliated companies

^[3]

8,439

8,214

Current Liabilities:

Accounts payable

557

856

Taxes accrued

Interest accrued

Customer deposits

102

Total current liabilities

191

137

1,038

1,340

Other Liabilities:

Deferred income taxes, net

470

406

Benefit obligations

1,219

1,227

Total long-term debt, net

428

329

Total other liabilities

2,214

2,060

Long-term Debt:

2,546

2,371

Commitments and Contingencies (Note 16)

Additional paid-in capital

Common stock

2,116

2,015

Retained earnings

515

423

Accumulated other comprehensive income (loss)

Total shareholders’ equity

2,641

2,443

Total Liabilities and Shareholders’ Equity

8,439

8,214

Series A Preferred Stock [Member]

Preferred Stock

790

Goodwill and Intangible Assets Disclosure [Abstract]

Preferred Stock

$ 950

[1]	CenterPoint Energy’s Cash and cash equivalents as of December 31, 2018 included $3.9 billion of temporary investments resulting from the Merger financings. CenterPoint Energy recorded interest income of $22 million, $28 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on CenterPoint Energy’s Statements of Consolidated Income. See Notes 13 and 14 for further details related to the Merger financings.
[2]	Houston Electric’s Cash and cash equivalents as of December 31, 2019 and 2018 included $216 million and $335 million, respectively, of cash related to the Bond Companies. Houston Electric recorded interest income of $9 million, $4 million and $2 million for the years ended December 31, 2019, 2018 and 2017, respectively, in Other, net on Houston Electric’s Statement of Consolidated Income.
[3]	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 11.

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

12 Months Ended

Dec. 31, 2019

Goodwill by Reportable Segments [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 December 31, 2019 are as follows:



	December 31, 2018		Additions (1)		Impairment		December 31, 2019
	(in millions)
Indiana Electric Integrated	$	—	$	1,121	$	—	$	1,121
Natural Gas Distribution	746		2,566		—		3,312
Energy Services (2)	110		—		48		62
Infrastructure Services	—		220		—		220
Corporate and Other	11		438		—		449
Total	$	867	$	4,345	$	48	$	5,164


(1)	This represents the allocation of goodwill to reportable segments from the Merger, changes from preliminary amounts previously reported and includes the final determination of fair value for each reportable segment. See Note 4.

(2)

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



	December 31, 2018		Impairment		December 31, 2019
			(in millions)
Natural Gas Distribution	$	746	$	—	$	746
Energy Services (1)	110		48		62
Corporate and Other	11		—		11
Total	$	867	$	48	$	819

(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]



	December 31, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships	$	86	$	(32	)	$	54	$	86	$	(27	)	$	59
Covenants not to compete	4		(4		)	—		4		(3		)	1
Other	16		(14		)	2		16		(11		)	5
Total	$	106	$	(50	)	$	56	$	106	$	(41	)	$	65



	December 31, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)
Customer relationships (1)	$	286	$	(43	)	$	243	$	86	$	(27	)	$	59
Covenants not to compete	4		(4		)	—		4		(3		)	1
Trade names (1)	58		(5		)	53		—		—			—
Construction backlog (1) (2)	27		(23		)	4		—		—			—
Operation and maintenance agreements (1) (2)	12		(1		)	11		—		—			—
Other (1)	24		(14		)	10		16		(11		)	5
Total	$	411	$	(90	)	$	321	$	106	$	(41	)	$	65


(1)	The fair value of intangible assets acquired through acquisitions has been finalized. See Note 4.

(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 Statements of Consolidated Income.

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



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization (1) (2)	$	25	$	10	$	13
Amortization expense of intangible assets recorded in Non-utility cost of revenues, including natural gas (2)	24		—		—


(1)	Includes $17 million for the year ended December 31, 2019 of amortization expense related to intangibles acquired in the Merger.

(2)

The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the year ended December 31, 2019, has been finalized. See Note 4.



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	9	$	10	$	13

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)
2020	$	29	$	6
2021	25		6
2022	25		6
2023	24		5
2024	22		5

Leases (Notes)

12 Months Ended

Dec. 31, 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. Sublease income is 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 ASC 842.

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



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease cost	$	25	$	—	$	5
Short-term lease cost	75		23		—
Variable lease cost	1		—		1
Total lease cost	$	101	$	23	$	6

The components of lease income were as follows:



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating lease income	$	4	$	2	$	1
Variable lease income	2		—		—
Total lease income	$	6	$	2	$	1

Supplemental balance sheet information related to leases was as follows:



	December 31, 2019
	CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	63		$	1		$	24
Total leased assets	$	63		$	1		$	24
Liabilities:
Current operating lease liability (2)	$	21		$	—		$	4
Non-current operating lease liability (3)	42			1			20
Total leased liabilities	$	63		$	1		$	24

Weighted-average remaining lease term (in years) - operating leases	5.1			5.2			7.7
Weighted-average discount rate - operating leases	3.42		%	3.52		%	3.67		%


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


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


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

As of December 31, 2019, maturities of operating lease liabilities were as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	22	$	1	$	6
2021	16		—		4
2022	9		—		4
2023	7		—		3
2024	3		—		2
2025 and beyond	12		—		9
Total lease payments	69		1		28
Less: Interest	6		—		4
Present value of lease liabilities	$	63	$	1	$	24

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 December 31, 2019, maturities of undiscounted operating lease payments to be received are as follows:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	3	$	1	$	1
2021	2		—		—
2022	2		—		—
2023	2		—		—
2024	2		—		—
2025 and beyond	10		—		—
Total lease payments to be received	$	21	$	1	$	1

Other information related to leases is as follows. See Note 20 for information on ROU assets obtained in exchange for operating lease liabilities:



	Year Ended December 31, 2019
	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	$	25	$	1	$	6

Earnings Per Share (CenterPoint Energy) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Income available to common shareholders - basic (1)

$ 791

$ 368

$ 1,792

Numerator:

$ 128

$ 241

$ 165

$ 140

$ 90

$ 153

$ (75)

$ 165

674

^[1]

333

^[1]

1,792

^[1]

Add back: Series B Preferred Stock dividend

117

Income available to common shareholders - diluted (1)

^[1]

$ 674

$ 333

$ 1,792

Denominator:

Weighted average common shares outstanding - basic

502,050,000

448,829,000

430,964,000

Plus: Incremental shares from assumed conversions:

Weighted average common shares outstanding - diluted

505,157,000

452,465,000

434,308,000

Basic Earnings Per Common Share

$ 0.25

^[2]

$ 0.48

^[2]

$ 0.33

^[2]

$ 0.28

^[2]

$ 0.18

^[2]

$ 0.35

^[2]

$ (0.17)

^[2]

$ 0.38

^[2]

$ 1.34

$ 0.74

$ 4.16

Diluted Earnings Per Common Share

$ 0.25

^[2]

$ 0.47

^[2]

$ 0.33

^[2]

$ 0.28

^[2]

$ 0.18

^[2]

$ 0.35

^[2]

$ (0.17)

^[2]

$ 0.38

^[2]

$ 1.33

$ 0.74

$ 4.13

Reduction in income taxes due to tax reform

$ 0

$ 1,113

^[3]

Preferred Stock Dividends, Income Statement Impact

$ 117

$ 35

$ 0

Restricted Stock [Member]

Plus: Incremental shares from assumed conversions:

Restricted stock (3)

^[4]

3,107,000

3,636,000

3,344,000

Add back: Series B Preferred Stock dividend

Numerator:

^[5]

$ 0

Plus: Incremental shares from assumed conversions:

Series B Preferred Stock (2)

^[5]

Preferred Stock Dividends, Income Statement Impact

$ 68

$ 17

$ 0

Amount of antidilutive securities excluded from computation of earnings per share

34,354,000

8,885,000

Defined Benefit Plan Disclosure [Line Items]

$ 190

[1]	Income available to common shareholders for the year ended December 31, 2019 includes net income from businesses acquired in the Merger of $190 million. See Note 4. Income available to common shareholders for the year ended December 31, 2017 includes a reduction in income tax expense of $1,113 million due to tax reform. See Note 15 for further discussion of the impacts of the TCJA.
[2]	Quarterly earnings (loss) per common share are based on the weighted average number of shares outstanding during the quarter, and the sum of the quarters may not equal annual earnings (loss) per common share.
[3]	Recognized a $1.1 billion deferred tax benefit from the remeasurement of CenterPoint Energy’s ADFIT liability as a result of the enactment of the TCJA on December 22, 2017, which reduced the U.S. corporate income tax rate from 35% to 21%.
[4]	The potentially dilutive impact from restricted stock awards applies the treasury stock method. Under this method, an increase in the average fair market value of Common Stock can result in a greater dilutive impact from these securities.
[5]	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 year ended December 31, 2019 and December 31, 2018 excludes Series B Stock Dividends of $68 million and $17 million, respectively, and 34,354,000 and 8,885,000 potentially dilutive shares, respectively, because to include them would be anti-dilutive. However, these shares could be potentially dilutive in the future.

Stock-Based Incentive Compensation Plans and Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2019

Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan [Table Text Block]

The following table summarizes CenterPoint Energy’s expenses related to LTIPs for 2019, 2018 and 2017:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
LTIP Compensation expense (1)	$	28	$	26	$	21
Income tax benefit recognized	7		6		8
Actual tax benefit realized for tax deductions	12		5		6

(1)

Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income and shown prior to any amounts capitalized.

Share-Based Compensation, Activity [Table Text Block]

The following tables summarize CenterPoint Energy’s LTIP activity for 2019:



	Year Ended December 31, 2019
	Shares (Thousands)		Weighted-Average Grant Date Fair Value		Remaining Average Contractual Life (Years)	Aggregate Intrinsic Value (2) (Millions)
Performance Awards (1)
Outstanding and non-vested as of December 31, 2018	3,818		$	23.91
Granted	1,413		31.16
Forfeited or canceled	(825	)	24.78
Vested and released to participants	(1,074	)	18.97
Outstanding and non-vested as of December 31, 2019	3,332		$	28.36	1.1	$	53

Stock Unit Awards
Outstanding and non-vested as of December 31, 2018	1,060		$	24.08
Granted	470		31.07
Forfeited or canceled	(131	)	27.95
Vested and released to participants	(433	)	20.72
Outstanding and non-vested as of December 31, 2019	966		$	28.46	1.2	$	26


(1)	Reflects maximum performance achievement.


(2)	Reflects the impact of current expectations of achievement and stock price.

Share-Based Compensation Arrangement By Award, Weighted Average Grant Date Fair Value, Grant Date Intrinsic Value, and Vested Grant Date Fair Value [Table Text Block]

The weighted average grant date fair values per unit of awards granted were as follows for 2019, 2018 and 2017:



	Year Ended December 31,
	2019		2018		2017
	(In millions, except for per unit amounts)
Performance Awards
Weighted-average grant date fair value per unit of awards granted	$	31.16	$	26.74	$	26.64
Total intrinsic value of awards received by participants	36		12		7
Vested grant date fair value	20		9		5

Stock Unit Awards
Weighted-average grant date fair value per unit of awards granted	$	31.07	$	26.62	$	26.77
Total intrinsic value of awards received by participants	15		9		9
Vested grant date fair value	9		7		7

Schedule of Multiemployer Plans [Table Text Block]

Federal law requires pensio

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

Amounts recognized in accumulated other comprehensive loss (gain) consist of the following:



	December 31,
	2019								2018
	Pension Benefits		Postretirement Benefits						Pension Benefits		Postretirement Benefits
	CenterPoint Energy		CenterPoint Energy			CERC			CenterPoint Energy		CenterPoint Energy			CERC
	(in millions)
Unrecognized actuarial loss (gain)	$	105	$	(16	)	$	(12	)	$	109	$	(7	)	$	(3	)
Unrecognized prior service cost	—		7			7			1		5			5
Deferred tax benefit	—		—			—			—		—			(9		)
Net amount recognized in accumulated other comprehensive loss (gain)	$	105	$	(9	)	$	(5	)	$	110	$	(2	)	$	(7	)

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



	Year Ended December 31,
	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:
Remeasurement of pension and other postretirement plans	7			—			7			(19		)	—			1
Deferred loss from interest rate derivatives (1)	(3		)	(1		)	—			(19		)	(18		)	(1		)
Reclassified to earnings	1			—			—			—			—			—
Other comprehensive loss from unconsolidated affiliates	(1		)	—			—			—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—			1			—			1
Actuarial losses (2)	8			—			—			6			—			—
Tax benefit (expense)	(3		)	—			(2		)	6			4			(1		)
Net current period other comprehensive income (loss)	10			(1		)	5			(25		)	(14		)	—
Adoption of ASU 2018-02	—			—			—			(15		)	—			(1		)
Ending Balance	$	(98	)	$	(15	)	$	10		$	(108	)	$	(14	)	$	5

(1)

(2)

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

Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]

The changes in plan assets and benefit obligations recognized in other comprehensive income during 2019 are as follows:



	Pension Benefits			Postretirement Benefits
	CenterPoint Energy			CenterPoint Energy			CERC
	(in millions)
Net loss (gain)	$	4		$	(8	)	$	(6	)
Amortization of net loss	(8		)	—			—
Amortization of prior service cost	(1		)	1			(1		)
Total recognized in comprehensive income	$	(5	)	$	(7	)	$	(7	)
Total expense recognized in net periodic costs and Other comprehensive income	$	87		$	1		$	(1	)

Benefit Plan Contributions [Table Text Block]

The Registrants made the following contributions in 2019 and expect to make the following minimum contributions in 2020 to the indicated benefit plans below:



	Contributions in 2019						Expected Minimum Contributions in 2020
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Qualified pension plans	$	86	$	—	$	—	$	76	$	—	$	—
Non-qualified pension plans	23		—		—		7		—		—
Postretirement benefit plans	17		10		3		17		9		3

Schedule of Expected Benefit Payments [Table Text Block]

The following benefit payments are expected to be paid by the pension and postretirement benefit plans:



	Pension Benefits		Postretirement Benefits
	CenterPoint Energy		CenterPoint Energy		Houston Electric		CERC
	(in millions)
2020	$	180	$	18	$	8	$	5
2021	178		18		8		4
2022	180		19		9		5
2023	181		20		10		5
2024	177		21		10		6
2025-2029	824		112		54		30

Defined Contribution Plan Disclosures [Table Text Block]



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Savings plan benefit expenses (1)	$	58	$	18	$	18	$	43	$	17	$	18	$	41	$	17	$	17

Other Benefit Plans [Table Text Block]

Expenses related to other benefit plans were recorded as follows:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Postemployment benefits	$	2	$	1	$	1	$	3	$	4	$	1	$	6	$	1	$	4
Deferred compensation plans	4		1		—		3		1		—		3		1		—

Amounts related to other benefit plans were included in Benefit Obligations in the Registrants’ accompanying Consolidated Balance Sheets as follows:



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Postemployment benefits	$	11	$	3	$	7	$	11	$	3	$	7
Deferred compensation plans	41		8		3		42		9		3
Split-dollar life insurance arrangements	32		1		—		36		1		—

Other Employee Matters [Table Text Block]

As of December 31, 2019, the Registrants’ employees were covered by collective bargaining agreements as follows:



		Percentage of Employees Covered
	Agreement Expiration	CenterPoint Energy		Houston Electric		CERC
IBEW Local 66	May 2020	10	%	51	%	—
OPEIU Local 12 and Mankato	March and May 2021	2	%	—		3	%
Gas Workers Union Local 340	April 2020	3	%	—		12	%
IBEW Locals 949 & 1393 and USW Locals 12213 & 7441	December 2020	4	%	—		7	%
USW Locals 13-227 & 13-1 and IBEW Local 702	June and July 2022	5	%	—		12	%
Teamsters Local 135	September 2021	—		—		—
UWUA Local 175	October 2021	1	%	—		—
Trade Agreements of Infrastructure Services through the DCA and PLCA (1)	Various expiration dates in 2020–2022	27	%	—		—
Total		52	%	51	%	34	%

(1)

Pension Plan [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Net Benefit Costs [Table Text Block]

CenterPoint Energy’s net periodic cost includes the following components relating to pension, including the non-qualified benefit plans:



	Year Ended December 31,
	2019			2018			2017
	(in millions)
Service cost (1)	$	40		$	37		$	36
Interest cost (2)	96			79			89
Expected return on plan assets (2)	(105		)	(107		)	(97		)
Amortization of prior service cost (2)	9			9			9
Amortization of net loss (2)	52			43			58
Settlement cost (2) (3)	2			—			—
Curtailment gain (2) (4)	(1		)	—			—
Net periodic cost	$	93		$	61		$	95


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


(2)	Amounts presented in the table above are included in Other, net in CenterPoint Energy’s 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. In 2019, CenterPoint Energy recognized a non-cash settlement cost 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 2019, CenterPoint Energy recognized a pension curtailment gain related to employees who were terminated after the Merger closed.

Schedule of Assumptions Used [Table Text Block]

CenterPoint Energy used the following assumptions to determine net periodic cost relating to pension benefits:



	Year Ended December 31,
	2019		2018		2017
Discount rate	4.35	%	3.65	%	4.15	%
Expected return on plan assets	6.00		6.00		6.00
Rate of increase in compensation levels	4.60		4.45		4.50

Schedule of Net Pension and Post-retirement Benefit Costs [Table Text Block]



	December 31,
	2019			2018
	(in millions, except for actuarial assumptions)
Change in Benefit Obligation
Benefit obligation, beginning of year	$	2,013		$	2,225
Plan obligations assumed in Merger	332			—
Service cost	40			37
Interest cost	96			79
Benefits paid	(244		)	(201		)
Actuarial (gain) loss (1)	216			(127		)
Plan amendment	1			—
Curtailment	(1		)	—
Benefit obligation, end of year	2,453			2,013
Change in Plan Assets
Fair value of plan assets, beginning of year	1,516			1,801
Plan assets assumed in Merger	286			—
Employer contributions	109			69
Benefits paid	(244		)	(201		)
Actual investment return	338			(153		)
Fair value of plan assets, end of year	2,005			1,516
Funded status, end of year	$	(448	)	$	(497	)

Amounts Recognized in Balance Sheets
Current liabilities-other	$	(8	)	$	(7	)
Other liabilities-benefit obligations	(440		)	(490		)
Net liability, end of year	$	(448	)	$	(497	)
Actuarial Assumptions
Discount rate (2)	3.20		%	4.35		%
Expected return on plan assets (3)	5.75			6.00
Rate of increase in compensation levels	4.95			4.60
Interest crediting rate	3.25			3.75


(1)	Significant sources of loss for 2019 include the decrease in discount rate from 4.35% to 3.20%. Significant sources of gain for 2018 include the increase in discount rate from 3.65% to 4.35% and the mortality projection scale change from MP2017 to MP2018.


(2)	The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.

(3)

The expected rate of return assumption was developed using the targeted asset allocation of CenterPoint Energy’s plans and the expected return for each asset class.

Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]

The following table displays pension benefits related to CenterPoint Energy’s pension plans that have accumulated benefit obligations in excess of plan assets:



	December 31,
	2019				2018
	Pension (Qualified)		Pension (Non-qualified)		Pension (Qualified)		Pension (Non-qualified)
	(in millions)
Accumulated benefit obligation	$	2,352	$	68	$	1,930	$	61
Projected benefit obligation	2,385		68		1,952		61
Fair value of plan assets	2,005		—		1,516		—

Target Allocation of Plan Assets [Table Text Block]

As part of the investment strategy discussed above, CenterPoint Energy maintained the following weighted average allocation targets for its pension plans as of December 31, 2019:



	Minimum		Maximum
U.S. equity	19	%	29	%
International equity	8	%	18	%
Real estate	3	%	9	%
Fixed income	52	%	62	%
Cash	0	%	2	%

Schedule of Allocation of Plan Assets [Table Text Block]

The following tables set forth by level, within the fair value hierarchy (see Note 10), CenterPoint Energy’s pension plan assets at fair value as of December 31, 2019 and 2018:



	Fair Value Measurements as of December 31,
	2019										2018
	(Level 1)			(Level 2)		(Level 3)		Total			(Level 1)			(Level 2)		(Level 3)		Total
	(in millions)
Cash	$	(7	)	$	—	$	—	$	(7	)	$	19		$	—	$	—	$	19
Corporate bonds:
Investment grade or above	—			699		—		699			—			368		—		368
Equity securities:
U.S. companies	69			—		—		69			60			—		—		60
Cash received as collateral from securities lending	61			—		—		61			77			—		—		77
U.S. treasuries	232			—		—		232			196			—		—		196
Mortgage backed securities	—			8		—		8			—			6		—		6
Asset backed securities	—			3		—		3			—			1		—		1
Municipal bonds	—			44		—		44			—			27		—		27
Mutual funds (2)	270			—		—		270			167			—		—		167
International government bonds	—			21		—		21			—			16		—		16
Obligation to return cash received as collateral from securities lending	(61		)	—		—		(61		)	(77		)	—		—		(77		)
Total investments at fair value	$	564		$	775	$	—	$	1,339		$	442		$	418	$	—	$	860
Investments measured by net asset value per share or its equivalent (1) (2)								666										656
Total Investments								$	2,005									$	1,516


(1)	Represents investments in common collective trust funds.


(2)	The amounts invested in mutual funds and common collective trust funds were allocated as follows:



	As of December 31,
	2019				2018
	Mutual Funds		Common Collective Trust Funds		Mutual Funds		Common Collective Trust Funds
International equities (1)	31	%	29	%	85	%	41	%
U.S. equities	49	%	51	%	15	%	5	%
Real estate	1	%	6	%	—	%	—	%
Fixed income	19	%	14	%	—	%	54	%

Postretirement Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Net Benefit Costs [Table Text Block]

Postretirement benefits are accrued over the active service period of employees. The net postretirement benefit cost includes the following components:



	Year Ended December 31,
	2019									2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	3		$	1		$	1		$	2		$	—		$	1		$	2		$	1		$	1
Interest cost (2)	15			7			5			13			8			4			16			9			5
Expected return on plan assets (2)	(5		)	(4		)	(1		)	(5		)	(4		)	(1		)	(5		)	(4		)	(1		)
Amortization of prior service cost (credit) (2)	(5		)	(6		)	1			(5		)	(5		)	1			(5		)	(6		)	1
Net postretirement benefit cost (credit)	$	8		$	(2	)	$	6		$	5		$	(1	)	$	5		$	8		$	—		$	6


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


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

Schedule of Assumptions Used [Table Text Block]

The following assumptions were used to determine net periodic cost relating to postretirement benefits:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
Discount rate	3.20	%	3.20	%	3.20	%	3.60	%	3.60	%	3.60	%	4.15	%	4.15	%	4.15	%
Expected return on plan assets	4.60		4.70		4.15		4.55		4.75		3.85		4.50		4.75		3.60

Schedule of Net Pension and Post-retirement Benefit Costs [Table Text Block]



	December 31,
	2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Change in Benefit Obligation
Benefit obligation, beginning of year	$	331		$	166		$	110		$	386		$	225		$	109
Plan obligations assumed in Merger	37			—			—			—			—			—
Service cost	3			1			1			2			—			1
Interest cost	15			7			5			13			8			4
Participant contributions	8			2			4			7			2			4
Benefits paid	(26		)	(13		)	(8		)	(25		)	(13		)	(9		)
Plan amendment	9			3			5			—			—			—
Actuarial (gain) loss (1)	(21		)	(4		)	(15		)	(52		)	(56		)	1
Benefit obligation, end of year	356			162			102			331			166			110
Change in Plan Assets
Fair value of plan assets, beginning of year	114			89			25			120			93			26
Employer contributions	17			10			3			14			9			4
Participant contributions	8			2			4			7			2			4
Benefits paid	(26		)	(13		)	(8		)	(25		)	(13		)	(9		)
Actual investment return	15			13			3			(2		)	(2		)	—
Fair value of plan assets, end of year	128			101			27			114			89			25
Funded status, end of year	$	(228	)	$	(61	)	$	(75	)	$	(217	)	$	(77	)	$	(85	)
Amounts Recognized in Balance Sheets
Current liabilities-other	$	(8	)	$	—		$	(3	)	$	(6	)	$	—		$	(3	)
Other liabilities-benefit obligations	(220		)	(61		)	(72		)	(211		)	(77		)	(82		)
Net liability, end of year	$	(228	)	$	(61	)	$	(75	)	$	(217	)	$	(77	)	$	(85	)
Actuarial Assumptions
Discount rate (2)	3.25		%	3.25		%	3.25		%	4.35		%	4.35		%	4.35		%
Expected return on plan assets (3)	3.95			4.05			3.35			4.60			4.70			4.15
Medical cost trend rate assumed for the next year - Pre-65	5.50			5.50			5.50			5.95			5.95			5.95
Medical/prescription drug cost trend rate assumed for the next year - Post-65	5.75			5.75			5.75			28.60			28.60			28.60
Prescription drug cost trend rate assumed for the next year - Pre-65	8.00			8.00			8.00			9.20			9.20			9.20
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	4.50			4.50			4.50			4.50			4.50			4.50
Year that the cost trend rates reach the ultimate trend rate - Pre-65	2028			2028			2028			2026			2026			2026
Year that the cost trend rates reach the ultimate trend rate - Post-65	2029			2029			2029			2027			2027			2027

(1)


(2)	The discount rate assumption was determined by matching the projected cash flows of the plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.


(3)	The expected rate of return assumption was developed using the targeted asset allocation of the plans and the expected return for each asset class.

Target Allocation of Plan Assets [Table Text Block]

As part of the investment strategy discussed above, the Registrants maintained the following weighted average allocation targets for the postretirement plans as of December 31, 2019:



	CenterPoint Energy				Houston Electric				CERC
	Minimum		Maximum		Minimum		Maximum		Minimum		Maximum
U.S. equity	13	%	23	%	13	%	23	%	15	%	25	%
International equity	3	%	13	%	3	%	13	%	2	%	12	%
Fixed income	69	%	79	%	69	%	79	%	68	%	78	%
Cash	0	%	2	%	0	%	2	%	0	%	2	%

Schedule of Allocation of Plan Assets [Table Text Block]

The following table presents mutual funds by level, within the fair value hierarchy, the Registrants’ postretirement plan assets at fair value as of December 31, 2019 and 2018:



	Fair Value Measurements as of December 31,
	2019								2018
	Mutual Funds
	(Level 1)		(Level 2)		(Level 3)		Total		(Level 1)		(Level 2)		(Level 3)		Total
	(in millions)
CenterPoint Energy	$	128	$	—	$	—	$	128	$	114	$	—	$	—	$	114
Houston Electric	101		—		—		101		89		—		—		89
CERC	27		—		—		27		25		—		—		25

The amounts invested in mutual funds were allocated as follows:



	As of December 31,
	2019						2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
Fixed income	71	%	71	%	69	%	74	%	74	%	73	%
U.S. equities	21	%	21	%	24	%	19	%	19	%	21	%
International equities	8	%	8	%	7	%	7	%	7	%	6	%

Equity (CenterPoint Energy) (Details)

12 Months Ended

Oct. 17, 2019

USD ($)

$ / shares

Jul. 31, 2019

USD ($)

$ / shares

Apr. 25, 2019

USD ($)

$ / shares

Dec. 12, 2018

USD ($)

$ / shares

Oct. 23, 2018

USD ($)

$ / shares

Oct. 01, 2018

USD ($)

$ / shares

Aug. 22, 2018

USD ($)

$ / shares

Jul. 26, 2018

USD ($)

$ / shares

Apr. 26, 2018

USD ($)

$ / shares

Dec. 13, 2017

USD ($)

$ / shares

Oct. 25, 2017

USD ($)

$ / shares

Jul. 27, 2017

USD ($)

$ / shares

Apr. 27, 2017

USD ($)

$ / shares

Jan. 05, 2017

USD ($)

$ / shares

Dec. 31, 2019

USD ($)

day

$ / shares

Dec. 31, 2018

USD ($)

$ / shares

Dec. 31, 2017

USD ($)

$ / shares

$ 0.86

$ 1.1200

$ 1.35

Preferred stock par value (in dollars per share) | $ / shares

$ 117,000,000

$ 35,000,000

$ 0

$ 0.01

Proceeds from the issuance of Series A Preferred Stock, net

$ 790,000,000

$ 0

$ 1,740,000,000

$ 0

Proceeds from issuance of common stock

1,844,000,000

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Beginning Balance

(108,000,000)

(68,000,000)

Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax

1,000,000

Other comprehensive loss from unconsolidated affiliates, net of tax

(1,000,000)

Net current period other comprehensive income (loss)

^[1]

1,000,000

Actuarial losses (2)

^[1]

8,000,000

6,000,000

Tax benefit (expense)

(3,000,000)

6,000,000

10,000,000

(25,000,000)

3,000,000

Ending Balance

(98,000,000)

(108,000,000)

$ (68,000,000)

Undistributed earnings from equity method investments included in retained earnings

$ 0

$ 31,000,000

Common Stock [Member]

Declaration Date

Oct. 17, 2019

Jul. 31, 2019

Apr. 25, 2019

Dec. 12, 2018

Oct. 23, 2018

Jul. 26, 2018

Apr. 26, 2018

Dec. 13, 2017

Oct. 25, 2017

Jul. 27, 2017

Apr. 27, 2017

Jan. 05, 2017

Record Date

Nov. 21, 2019

Aug. 15, 2019

May 16, 2019

Feb. 21, 2019

Nov. 15, 2018

Aug. 16, 2018

May 17, 2018

Feb. 15, 2018

Nov. 16, 2017

Aug. 16, 2017

May 16, 2017

Feb. 16, 2017

Payment Date

Dec. 12, 2019

Sep. 12, 2019

Jun. 13, 2019

Mar. 14, 2019

Dec. 13, 2018

Sep. 13, 2018

Jun. 14, 2018

Mar. 08, 2018

Dec. 08, 2017

Sep. 08, 2017

Jun. 09, 2017

Mar. 10, 2017

$ 0.2875

$ 0.2775

$ 0.2675

$ 0.8625

$ 1.1200

$ 1.3475

Dividends declared

$ 144,000,000

$ 145,000,000

$ 144,000,000

$ 139,000,000

$ 120,000,000

$ 116,000,000

$ 115,000,000

$ 433,000,000

$ 523,000,000

$ 581,000,000

Common stock issued per share price | $ / shares

69,633,027

$ 27.25

Proceeds from issuance of common stock

$ 1,844,000,000

Series A Preferred Stock [Member]

Declaration Date

Jul. 31, 2019

Dec. 12, 2018

Record Date

Aug. 15, 2019

Feb. 15, 2019

Payment Date

Sep. 03, 2019

Mar. 01, 2019

$ 30.6250

$ 32.1563

$ 30.6250

$ 32.1563

$ 0.0000

Dividends declared

$ 24,000,000

$ 26,000,000

$ 24,000,000

$ 26,000,000

$ 49,000,000

$ 18,000,000

$ 0

Preferred stock par value (in dollars per share) | $ / shares

800,000

$ 1,000

$ 0.01

Preferred stock liquidation preference

$ 800,000,000

Preferred stock liquidation preference (per share) | $ / shares

$ 1,000

Preferred stock dividend rate

6.125%

Preferred stock redemption price (per share) | $ / shares

$ 1,000

Preferred stock convertible threshold (in days) | day

120

Declaration Date

Oct. 17, 2019

Jul. 31, 2019

Apr. 25, 2019

Dec. 12, 2018

Oct. 23, 2018

Record Date

Nov. 15, 2019

Aug. 15, 2019

May 15, 2019

Feb. 15, 2019

Nov. 15, 2018

Payment Date

Dec. 02, 2019

Sep. 03, 2019

Jun. 03, 2019

Mar. 01, 2019

Dec. 01, 2018

$ 17.5000

$ 11.6667

$ 52.5000

$ 29.1667

$ 0.0000

Dividends declared

$ 17,000,000

$ 11,000,000

$ 51,000,000

$ 28,000,000

Preferred stock par value (in dollars per share) | $ / shares

$ 68,000,000

$ 17,000,000

$ 0

$ 0.01

Preferred stock liquidation preference

$ 977,500,000

Preferred stock liquidation preference (per share) | $ / shares

$ 1,000

Preferred stock dividend rate

7.00%

Proceeds from the issuance of Series B Preferred Stock, net

$ 950,000,000

Depositary Share, Conversion Ratio

0.05

Preferred Stock, Convertible, Conversion Price | $ / shares

$ 1,000

Preferred stock threshold consecutive calendar days | day

Depositary Share [Member]

Depositary share par value (in dollars per depositary share) | $ / shares

19,550,000

$ 50

Number of depositary shares eligible for conversion (in shares) | shares

120 Days After Conclusion of Review or Appeal [Member] | Series A Preferred Stock [Member]

Preferred stock redemption price (per share) | $ / shares

$ 1,020

Preferred stock redemption percentage liquidation value

102.00%

London Interbank Offered Rate (LIBOR) [Member] | Series A Preferred Stock [Member]

Preferred stock dividend rate

3.27%

Over-Allotment Option [Member] | Common Stock [Member]

Over-Allotment Option [Member] | Series B [Member]

9,082,568

Minimum [Member] | Series B Preferred Stock [Member]

2,550,000

Preferred Stock, Convertible, Stock Price Trigger | $ / shares

$ 27.2494

Minimum [Member] | Series B [Member]

30.5820

Preferred Stock, Convertible, Stock Price Trigger | $ / shares

$ 27.2494

Minimum [Member] | Depositary Share [Member]

Maximum [Member] | Series B Preferred Stock [Member]

1.5291

Preferred Stock, Convertible, Stock Price Trigger | $ / shares

$ 32.6990

Maximum [Member] | Series B [Member]

36.6980

Preferred Stock, Convertible, Stock Price Trigger | $ / shares

$ 32.6990

Maximum [Member] | Depositary Share [Member]

Interest Rate Contract [Member]

1.8349

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

^[2]

$ (3,000,000)

(19,000,000)

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

Gain (loss) reclassified from accumulated OCI into income

1,000,000

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Beginning Balance

(14,000,000)

Net current period other comprehensive income (loss)

^[1]

Actuarial losses (2)

^[1]

Tax benefit (expense)

4,000,000

(1,000,000)

(14,000,000)

(1,000,000)

Ending Balance

(15,000,000)

(14,000,000)

Houston Electric [Member] | Interest Rate Contract [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

^[2]

(1,000,000)

(18,000,000)

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

Gain (loss) reclassified from accumulated OCI into income

1,000,000

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Beginning Balance

5,000,000

6,000,000

Net current period other comprehensive income (loss)

^[1]

1,000,000

Actuarial losses (2)

^[1]

Tax benefit (expense)

(2,000,000)

(1,000,000)

5,000,000

3,000,000

Ending Balance

10,000,000

5,000,000

$ 6,000,000

CERC Corp [Member] | Interest Rate Contract [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

^[2]

(1,000,000)

CERC Corp [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Interest Expense [Member]

Gain (loss) reclassified from accumulated OCI into income

1,000,000

Pension and Other Postretirement Plans [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

7,000,000

(19,000,000)

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

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

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

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Other comprehensive income (loss) before reclassifications:

7,000,000

1,000,000

Adoption of ASU 2018-02 [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Adoption of ASU 2018-02

(15,000,000)

Adoption of ASU 2018-02 [Member] | Houston Electric [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Adoption of ASU 2018-02

Adoption of ASU 2018-02 [Member] | CERC Corp [Member]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

Adoption of ASU 2018-02

$ 0

$ (1,000,000)

[1]

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

[2]

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

12 Months Ended

Dec. 31, 2019

USD ($)

Change in Accounts Receivable [Roll Forward]

$ 516

^[1]

Increase (Decrease) in Accounts Receivable

800

284

Change in Other Accrued Unbilled Revenues [Roll Forward]

373

^[1]

Increase (Decrease) in Other Accrued Unbilled Revenues

579

206

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

Contract with Customer, Liability, Revenue Recognized

Change in Accounts Receivable [Roll Forward]

234

Increase (Decrease) in Accounts Receivable

210

(24)

Change in Other Accrued Unbilled Revenues [Roll Forward]

110

Increase (Decrease) in Other Accrued Unbilled Revenues

117

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

282

Change in Other Accrued Unbilled Revenues [Roll Forward]

263

Increase (Decrease) in Other Accrued Unbilled Revenues

250

$ (13)

[1]	Opening balances related to Vectren are as of February 1, 2019, and are thus excluded from the opening balance as of December 31, 2018.

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Public Utilities General Disclosures [Table Text Block]



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Interest and AFUDC debt (1)	$	36	$	8	$	3	$	8	$	6	$	2	$	9	$	6	$	2
AFUDC equity (2)	22		15		3		12		10		2		11		10		1


(1)	Included in Interest and other finance charges on the Registrants’ respective Statements of Consolidated Income.

(2)

Included in Other Income (Expense) on the Registrants’ respective Statements of Consolidated Income.

Provision for doubtful accounts [Table Text Block]

The table below summarizes the Registrants’ provision for doubtful accounts for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Provision for doubtful accounts	$	16	$	—	$	12	$	16	$	—	$	16	$	14	$	1	$	13

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 will result in an immaterial adjustment to the carrying value of the Registrants’ accounts receivable, net. The adoption of this standard will not 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 10 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’ consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ statements of consolidated income. The adoption of this standard will not have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures.

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment [Table Text Block]

As of December 31, 2019, minimum purchase obligations are approximately:



	CenterPoint Energy		CERC
	(in millions)
2020	$	750	$	533
2021	617		432
2022	418		242
2023	335		182
2024	271		174
2025 and beyond	1,888		1,526

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



	December 31, 2019
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	12	$	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

Property, Plant and Equipment (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Property, Plant and Equipment, Net, by Type [Abstract]

$ 30,685

$ 20,267

9,740

6,223

Depreciation and Amortization [Abstract]

20,945

14,044

Depreciation

920

626

$ 619

Amortization of securitized regulatory assets

271

531

329

Other amortization

Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]

1,287

1,243

1,036

Asset Retirement Obligation Addition from Merger with Vectren

258

281

116

Accretion expense (1)

^[1]

Revisions in estimates (2)

^[2]

149

(33)

Ending balance

539

258

281

Property, Plant and Equipment, Net, by Type [Abstract]

12,829

12,148

3,797

3,746

Depreciation and Amortization [Abstract]

9,032

8,402

Depreciation

339

342

354

Amortization of securitized regulatory assets

271

531

329

Other amortization

Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]

648

917

724

Revisions in estimates (2)

Accretion expense (1)

^[1]

^[2]

(2)

Ending balance

Property, Plant and Equipment, Net, by Type [Abstract]

8,124

7,431

2,288

2,205

Depreciation and Amortization [Abstract]

5,836

5,226

Depreciation

281

264

243

Other amortization

Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]

305

293

279

Revisions in estimates (2)

221

243

Accretion expense (1)

^[1]

^[2]

(31)

Ending balance

325

221

$ 243

Electric Transmission and Distribution [Member]

Property, Plant and Equipment, Net, by Type [Abstract]

14,360

12,148

4,634

3,746

Electric Transmission and Distribution [Member] | Weighted Average [Member]

$ 9,726

8,402

Property, Plant and Equipment, Net, by Type [Abstract]

Electric Generation Equipment [Member]

37 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 1,780

^[3]

698

^[3]

Electric Generation Equipment [Member] | Weighted Average [Member]

$ 1,082

^[3]

Property, Plant and Equipment, Net, by Type [Abstract]

Electric Transmission [Member] | Houston Electric [Member]

27 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 3,358

3,077

674

650

Electric Transmission [Member] | Houston Electric [Member] | Weighted Average [Member]

$ 2,684

2,427

Property, Plant and Equipment, Net, by Type [Abstract]

Electric Distribution [Member] | Houston Electric [Member]

46 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 7,876

7,524

2,586

2,553

Electric Distribution [Member] | Houston Electric [Member] | Weighted Average [Member]

$ 5,290

4,971

Property, Plant and Equipment, Net, by Type [Abstract]

35 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 12,695

7,257

3,731

2,128

Natural Gas Distribution [Member] | Weighted Average [Member]

$ 8,964

5,129

Property, Plant and Equipment, Net, by Type [Abstract]

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

29 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 7,933

7,257

2,208

2,128

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

$ 5,725

5,129

Property, Plant and Equipment, Net, by Type [Abstract]

29 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 136

^[4]

121

^[4]

Energy Services [Member] | Weighted Average [Member]

$ 83

^[4]

Property, Plant and Equipment, Net, by Type [Abstract]

Energy Services [Member] | CERC Corp [Member]

27 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 136

^[4]

121

^[4]

Energy Services [Member] | CERC Corp [Member] | Weighted Average [Member]

$ 83

^[4]

Property, Plant and Equipment, Net, by Type [Abstract]

27 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 317

^[5]

^[5]

Infrastructure Services [Member] | Weighted Average [Member]

$ 295

^[5]

Property, Plant and Equipment, Net, by Type [Abstract]

Property, Plant and Equipment, Net, by Type [Abstract]

10 years

Other property [Member]

$ 1,397

741

602

306

Other property [Member] | Weighted Average [Member]

$ 795

435

Property, Plant and Equipment, Net, by Type [Abstract]

Other property [Member] | Houston Electric [Member]

19 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 1,595

1,547

537

543

Other property [Member] | Houston Electric [Member] | Weighted Average [Member]

$ 1,058

1,004

Property, Plant and Equipment, Net, by Type [Abstract]

Other property [Member] | CERC Corp [Member]

19 years

Property, Plant and Equipment, Net, by Type [Abstract]

$ 55

Other property [Member] | CERC Corp [Member] | Weighted Average [Member]

$ 28

$ 19

Property, Plant and Equipment, Net, by Type [Abstract]

Property, Plant and Equipment, Net, by Type [Abstract]

16 years

SIGECO [Member]

SIGECO's share of cost of Warrick Unit 4

$ 194

SIGECO's share of accumulated depreciation of Warrick Unit 4

$ 137

[1]	Reflected in Regulatory assets on each of the Registrants’ respective Consolidated Balance Sheets.
[2]	In 2019, the Registrants reflected an increase in their respective ARO liability, which is primarily attributable to decreases in the long-term interest rates used for discounting in the ARO calculation and increased estimated closure costs for CenterPoint Energy’s electric generation. In 2018, CenterPoint Energy and CERC reflected a decrease in their respective ARO liability, which is primarily attributable to increases in the long-term interest rates used for discounting in the ARO calculation.
[3]	SIGECO and AGC own a 300 MW unit at the Warrick Power Plant (Warrick Unit 4) as tenants in common. SIGECO’s share of the cost of this unit as of December 31, 2019, is $194 million with accumulated depreciation totaling $137 million. AGC and SIGECO share equally in the cost of operation and output of the unit. SIGECO’s share of operating costs is included in Operation and maintenance expense in CenterPoint Energy’s Statements of Consolidated Income.
[4]	On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.
[5]	On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Securities Purchase Agreement to sell the businesses within its Infrastructure Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

STATEMENTS OF CONSOLIDATED SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares						12 Months Ended
	Oct. 17, 2019	Jul. 31, 2019	Apr. 25, 2019	Dec. 12, 2018	Oct. 23, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Aug. 22, 2018
Cumulative preferred stock par value (in dollars per share)						$ 0.01	$ 0.01	$ 0.01
Cumulative preferred stock shares authorized (in shares)						20,000,000	20,000,000	20,000,000
Common stock shares par value (in dollars per share)						$ 0.01	$ 0.01	$ 0.01
Common stock shares authorized (in shares)						1,000,000,000	1,000,000,000	1,000,000,000
Common stock dividends declared per share						$ 0.86	$ 1.1200	$ 1.35
Series A Preferred Stock [Member]
Cumulative preferred stock par value (in dollars per share)						0.01	0.01		$ 1,000
Preferred stock dividends declared per share		$ 30.6250		$ 32.1563		30.6250	32.1563	0.0000
Series B Preferred Stock [Member]
Cumulative preferred stock par value (in dollars per share)						0.01	0.01
Preferred stock dividends declared per share	$ 17.5000	$ 17.5000	$ 17.5000	$ 17.5000	$ 11.6667	$ 52.5000	$ 29.1667	$ 0.0000

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2019

Property, Plant and Equipment [Abstract]

Schedule of Property, Plant and Equipment [Table Text Block]

Property, plant and equipment includes the following:



		December 31, 2019						December 31, 2018
	Weighted Average Useful Lives	Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net		Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net
	(in years)	(in millions)
CenterPoint Energy
Electric Transmission & Distribution	37	$	14,360	$	4,634	$	9,726	$	12,148	$	3,746	$	8,402
Electric Generation (1)	27	1,780		698		1,082		—		—		—
Natural Gas Distribution	29	12,695		3,731		8,964		7,257		2,128		5,129
Energy Services (2)	27	136		53		83		121		43		78
Infrastructure Services (3)	10	317		22		295		—		—		—
Other property	19	1,397		602		795		741		306		435
Total		$	30,685	$	9,740	$	20,945	$	20,267	$	6,223	$	14,044
Houston Electric
Electric Transmission	46	$	3,358	$	674	$	2,684	$	3,077	$	650	$	2,427
Electric Distribution	35	7,876		2,586		5,290		7,524		2,553		4,971
Other transmission & distribution property	19	1,595		537		1,058		1,547		543		1,004
Total		$	12,829	$	3,797	$	9,032	$	12,148	$	3,746	$	8,402



		December 31, 2019						December 31, 2018
	Weighted Average Useful Lives	Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net		Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net
	(in years)	(in millions)
CERC
Natural Gas Distribution	29	$	7,933	$	2,208	$	5,725	$	7,257	$	2,128	$	5,129
Energy Services (2)	27	136		53		83		121		43		78
Other property	16	55		27		28		53		34		19
Total		$	8,124	$	2,288	$	5,836	$	7,431	$	2,205	$	5,226

(1)


(2)	On February 24, 2020, CenterPoint Energy, through its subsidiary CERC Corp., entered into the Equity Purchase Agreement to sell CES, which represents substantially all of the businesses within the Energy Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.


(3)	On February 3, 2020, CenterPoint Energy, through its subsidiary VUSI, entered into the Securities Purchase Agreement to sell the businesses within its Infrastructure Services reportable segment. The transaction is expected to close in the second quarter of 2020. For further information, see Notes 6 and 23.

Depreciation and Amortization [Table Text Block]

The following table presents depreciation and amortization expense for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Depreciation	$	920	$	339	$	281	$	626	$	342	$	264	$	619	$	354	$	243
Amortization of securitized regulatory assets	271		271		—		531		531		—		329		329		—
Other amortization	96		38		24		86		44		29		88		41		36
Total	$	1,287	$	648	$	305	$	1,243	$	917	$	293	$	1,036	$	724	$	279

Asset Retirement Obligation [Table Text Block]

A reconciliation of the changes in the ARO liability recorded in Other non-current liabilities on each of the Registrants’ respective Consolidated Balance Sheets is as follows:



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning balance	$	258	$	34	$	221	$	281		$	35		$	243
Addition from Merger with Vectren	116		—		—		—			—			—
Accretion expense (1)	16		1		10		10			1			9
Revisions in estimates (2)	149		7		94		(33		)	(2		)	(31		)
Ending balance	$	539	$	42	$	325	$	258		$	34		$	221


(1)	Reflected in Regulatory assets on each of the Registrants’ respective Consolidated Balance Sheets.

(2)

Regulatory Matters Houston Electric Base Rate Case (Details) - USD ($) $ in Millions	Jan. 23, 2020	Apr. 05, 2019	Dec. 31, 2019	Dec. 31, 2018
Public Utilities, General Disclosures [Line Items]
Non-current regulatory assets			$ 2,117	$ 1,967
CenterPoint Energy Houston Electric 2019 Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Revenue increase		$ 194
Rate base		$ 6,400
Debt capital structure		50.00%
Equity capital structure		50.00%
Return on equity		10.40%
Houston Electric Stipulation and Settlement Agreement [Member] \| Public Utility Commission of Texas [Member]
Public Utilities, General Disclosures [Line Items]
General mortgage bonds used as collateral			68
Subsequent Event [Member] \| Houston Electric Stipulation and Settlement Agreement [Member] \| Public Utility Commission of Texas [Member]
Public Utilities, General Disclosures [Line Items]
Revenue increase	$ 13
Debt capital structure	57.50%
Equity capital structure	42.50%
Return on equity	9.40%
Unprotected Excess Deferred Income Tax	$ 105
Rate Case Expense [Member] \| Houston Electric Stipulation and Settlement Agreement [Member]
Public Utilities, General Disclosures [Line Items]
Non-current regulatory assets			$ 12

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

3 Months Ended

12 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

$ 9,151

$ 6,745

$ 6,124

3,311

4,024

3,568

^[1]

(34)

Electric Transmission & Distribution [Member]

$ 3,230

$ 2,742

$ 2,798

$ 3,531

$ 3,036

$ 2,212

$ 2,186

$ 3,155

12,301

10,589

9,614

Indiana Electric Integrated [Member]

^[2]

2,996

3,232

2,997

^[2]

523

3,643

2,931

2,606

3,653

4,411

3,997

Corporate and Other [Member]

^[3]

1,186

Intersegment Eliminations [Member]

300

Intersegment Eliminations [Member] | Electric Transmission & Distribution [Member]

(173)

(146)

(85)

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

Intersegment Eliminations [Member] | Energy Services [Member]

(40)

(36)

(33)

Intersegment Eliminations [Member] | Infrastructure Services [Member]

(129)

(110)

(52)

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

(4)

Reportable Subsegments [Member] | Electric Transmission & Distribution [Member]

^[4]

2,984

3,235

3,001

^[4]

(2)

(1)

^[1],[4]

(1)

(3)

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

^[4]

2,996

3,232

2,997

^[4]

523

^[5]

^[4]

^[5]

^[1],[4]

^[5]

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

^[4]

523

^[5]

^[4]

3,680

^[5]

3,011

2,638

^[4]

^[5]

(2)

^[1],[4]

^[5]

(42)

Reportable Subsegments [Member] | Energy Services [Member]

^[4]

3,643

^[5]

2,931

2,606

^[6]

479

493

480

^[6]

3,303

4,028

3,569

^[1],[6]

Reportable Subsegments [Member] | Infrastructure Services [Member]

^[6]

3,653

4,411

3,997

^[6]

1,190

^[5]

^[6]

^[1],[6]

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

^[6]

1,186

^[5]

^[6]

295

^[5]

^[6]

^[1],[6]

^[5]

Reportable Subsegments [Member] | Intersegment Eliminations [Member]

^[6]

300

^[5]

^[4]

(40)

^[5]

(36)

(33)

^[6]

(129)

(110)

(52)

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

(173)

(146)

(85)

^[6]

(4)

^[5]

Houston Electric [Member] | Reportable Subsegments [Member] | Electric Transmission & Distribution [Member]

680

859

765

686

728

897

854

755

2,990

3,234

2,998

2,984

3,235

3,001

^[7]

(1)

(3)

2,990

3,234

2,998

3,430

3,505

3,118

3,304

4,026

3,569

^[8]

(42)

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

$ 1,734

$ 1,126

$ 1,342

$ 2,368

$ 2,303

^[9]

$ 1,312

^[9]

$ 1,328

^[9]

$ 2,400

^[9]

6,570

7,343

6,603

2,911

2,931

2,606

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

3,654

4,411

3,997

CERC Corp [Member] | Intersegment Eliminations [Member]

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

(168)

(146)

(85)

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

(40)

(36)

(33)

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

(128)

(110)

(52)

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

^[10]

2,945

3,011

2,638

^[10]

(2)

^[8],[10]

(42)

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

^[10]

2,911

2,931

2,606

^[11]

480

493

480

^[11]

3,302

4,028

3,569

^[8],[11]

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

^[11]

3,654

4,411

3,997

^[11]

^[11]

^[8],[11]

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

^[11]

^[10]

(40)

(36)

(33)

^[11]

(128)

(110)

(52)

Supplemental Cash Flow Elements [Abstract]

$ (168)

$ (146)

$ (85)

[1]

[2]

CenterPoint Energy’s Houston Electric T&D’s revenues from major customers are as follows:



	Year Ended December 31,
	2019		2018		2017
	(in millions)
Affiliates of NRG	$	727	$	705	$	713
Affiliates of Vistra Energy Corp.	263		251		229

[3]

[4]

Reflected in Utility revenues in the Statements of Consolidated Income.

[5]

Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to December 31, 2019.

[6]

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

[7]

[8]

[9]

Amounts have been recast to reflect discontinued operations in all periods presented.

[10]

Reflected in Utility revenues in the Statements of Consolidated Income.

[11]

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

Supplemental Disclosure of Cash Flow Information

12 Months Ended

Dec. 31, 2019

Supplemental Disclosure of Cash Flow Information [Text Block]

(20) Supplemental Disclosure of Cash Flow Information

The tables below provide supplemental disclosure of cash flow information:



	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	436	$	229	$	109	$	363	$	200	$	105	$	378	$	205	$	116
Income taxes (refunds), net	155		87		7		89		154		3		15		76		4
Non-cash transactions:
Accounts payable related to capital expenditures	236		117		86		201		124		80		144		104		56
Capital distribution associated with the Internal Spin (1)	—		—		28		—		—		1,473		—		—		—
ROU assets obtained in exchange for lease liabilities (2)	44		1		29		—		—		—		—		—		—


(1)	The capital distribution in 2019 associated with the Internal Spin is a result of the return to accrual for the periods of CERC’s ownership during 2018.


(2)	Includes the transition impact of adoption of ASU 2016-02 Leases as of January 1, 2019. The Registrants elected not to recast comparative periods in the year of adoption as permitted by the standard.



	December 31, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash and cash equivalents (1) (2)	$	241	$	216	$	2	$	4,231	$	335	$	14
Restricted cash included in Prepaid expenses and other current assets	30		19		—		46		34		11
Restricted cash included in Other	—		—		—		1		1		—
Total cash, cash equivalents and restricted cash shown in Statements of Consolidated Cash Flows	$	271	$	235	$	2	$	4,278	$	370	$	25

(1)

(2)

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Summary of Significant Accounting Policies [Text Block]

Summary of Significant Accounting Policies


(a)	Use of Estimates


(b)	Principles of Consolidation


(c)	Equity and Investments without a Readily Determinable Fair Value (CenterPoint Energy)

Investments without a readily determinable fair value will be measured at cost, less impairment, plus or minus observable prices changes of an identical or similar investment of the same issuer.


(d)	Revenues

(e) MISO Transactions

(f) Guarantees

(g) Long-lived Assets, Goodwill and Intangibles

The Registrants record property, plant and equipment at historical cost and expense repair and maintenance costs as incurred.

(h) Assets Held for Sale and Discontinued Operations

(i) Regulatory Assets and Liabilities

For further detail on the Registrants’ regulatory assets and liabilities, see Note 7.

(j) Depreciation and Amortization Expense

(k) Capitalization of Interest and AFUDC



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Interest and AFUDC debt (1)	$	36	$	8	$	3	$	8	$	6	$	2	$	9	$	6	$	2
AFUDC equity (2)	22		15		3		12		10		2		11		10		1


(1)	Included in Interest and other finance charges on the Registrants’ respective Statements of Consolidated Income.


(2)	Included in Other Income (Expense) on the Registrants’ respective Statements of Consolidated Income.

(l) Income Taxes

To the extent certain EDIT of the Registrants’ rate-regulated subsidiaries may be recoverable or payable through future rates, regulatory assets and liabilities have been recorded, respectively.

The Registrants use the portfolio approach to recognize income tax effects on other comprehensive income from accumulated other comprehensive income.

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

(m) Accounts Receivable and Allowance for Doubtful Accounts

The table below summarizes the Registrants’ provision for doubtful accounts for 2019, 2018 and 2017:



	Year Ended December 31,
	2019						2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Provision for doubtful accounts	$	16	$	—	$	12	$	16	$	—	$	16	$	14	$	1	$	13

(n) Inventory

(o) Derivative Instruments

(p) Investments in Equity Securities (CenterPoint Energy and CERC)

(q) Environmental Costs

(r) Cash and Cash Equivalents and Restricted Cash

(s) Preferred Stock and Dividends

(t) Purchase Accounting

(u) 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 will result in an immaterial adjustment to the carrying value of the Registrants’ accounts receivable, net. The adoption of this standard will not 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 10 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’ consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ statements of consolidated income. The adoption of this standard will not have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures.

Derivative Instruments (Tables)

12 Months Ended

Dec. 31, 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:



	December 31, 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 summarizes CenterPoint Energy’s and CERC’s weather hedge gain (loss) activity:

CenterPoint Energy



				Year Ended December 31,
Texas Operations	Winter Season	Bilateral Cap		2019		2018			2017
		(in millions)
NGD	2019 – 2020	$	8	$	2	$	—		$	—
NGD	2018 – 2019	9		—		—			—
NGD	2017 – 2018	8		—		(2		)	—
Electric operations	2019 – 2020	7		3		—			—
Electric operations	2018 – 2019	8		3		—			—
Electric operations	2017 – 2018	9		—		(2		)	—
Electric operations	2016 – 2017	9		—		—			(1		)
Total CenterPoint Energy (1)				$	8	$	(4	)	$	(1	)

CERC



				Year Ended December 31,
Texas Operations	Winter Season	Bilateral Cap		2019		2018			2017
		(in millions)
NGD	2019 – 2020	$	8	$	2	$	—		$	—
NGD	2018 – 2019	9		—		—			—
NGD	2017 – 2018	8		—		(2		)	—
Total CERC (1)				$	2	$	(2	)	$	—

(1)

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

Fair Value of Derivative Instruments [Table Text Block]

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy



		December 31, 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	12		—		1		7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	139		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	58		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	73		184		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	10		54		16		25
Interest rate derivatives	Other Liabilities	—		10		—		—
Indexed debt securities derivative	Current Liabilities	—		893		—		601
Total CenterPoint Energy		$	292	$	1,144	$	220	$	833


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 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



		December 31, 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



		December 31, 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	$	12	$	—	$	1	$	7
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	139		3		103		3
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	58		—		38		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	73		177		62		173
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	10		39		16		25
Total CERC		$	292	$	219	$	220	$	208


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 2,226 Bcf or a net 374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of December 31, 2019 and 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)



CenterPoint Energy
		December 31, 2019					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			Carrying Amount of Hedged Assets/(Liabilities)		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	47	$	(13	)	$	57	$	1
Total CenterPoint Energy		$	47	$	(13	)	$	57	$	1



CERC
		December 31, 2019					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			Carrying Amount of Hedged Assets/(Liabilities)		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	47	$	(13	)	$	57	$	1
Total CERC		$	47	$	(13	)	$	57	$	1

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



CenterPoint Energy
	December 31, 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	$	224		$	(88	)	$	136		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	68			(10		)	58			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(187		)	136			(51		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(54		)	25			(29		)	(25		)	20			(5		)
Total CenterPoint Energy	$	51		$	63		$	114		$	12		$	19		$	31



CERC
	December 31, 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	$	224		$	(88	)	$	136		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	68			(10		)	58			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(180		)	136			(44		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(39		)	25			(14		)	(25		)	20			(5		)
Total CERC	$	73		$	63		$	136		$	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 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)



CenterPoint Energy	Year Ended December 31,
	2019			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	4,029		$	4,364		$	3,785

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(14		)	(13		)	14
Derivatives designated as hedging instruments	14			13			(14		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(213		)	(149		)	(67		)


(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 the years ended December 31, 2019, 2018 and 2017, respectively.



CERC	Year Ended December 31,
	2019			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	3,503		$	4,364		$	3,785

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(14		)	(13		)	14
Derivatives designated as hedging instruments	14			13			(14		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(213		)	(149		)	(67		)


(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 the years ended December 31, 2019, 2018 and 2017, respectively.

CenterPoint Energy



		Year Ended December 31,
	Income Statement Location	2019			2018			2017
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (Losses) in Non-utility revenues	$	214		$	107		$	211
Indexed debt securities derivative	Gain (loss) on indexed debt securities	(292		)	(232		)	49
Interest rate derivatives	Gains in Other Income (Expense)	—			2			—
Total CenterPoint Energy		$	(78	)	$	(123	)	$	260

CERC



		Year Ended December 31,
	Income Statement Location	2019		2018		2017
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (Losses) in Non-utility revenues	$	214	$	107	$	211
Total CERC		$	214	$	107	$	211

Credit Quality of Counterparties [Table Text Block]



	December 31, 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		—		—

(d) Credit Quality of Counterparties (CenterPoint Energy and CERC)

CenterPoint Energy



	December 31, 2019				December 31, 2018
	Investment Grade (1)		Total (3)		Investment Grade (1)		Total (3)
	(in millions)
Energy marketers	$	4	$	16	$	11	$	24
End users (2)	27		178		30		114
Total CenterPoint Energy	$	31	$	194	$	41	$	138

CERC



	December 31, 2019				December 31, 2018
	Investment Grade (1)		Total (3)		Investment Grade (1)		Total (3)
	(in millions)
Energy marketers	$	4	$	16	$	11	$	24
End users (2)	27		178		30		114
Total CERC	$	31	$	194	$	41	$	138


(1)	“Investment grade” is primarily determined using publicly available credit ratings and considers credit support (including parent company guarantees) and collateral (including cash and standby letters of credit). For unrated counterparties, CERC determines a synthetic credit rating by performing financial statement analysis and consider contractual rights and restrictions and collateral.


(2)	End users are comprised primarily of customers who have contracted to fix the price of a portion of their physical gas requirements for future periods.

(3)

The amounts reflected in the table above were not impacted by collateral netting.

Operating Leases, Lease Income [Abstract]

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).

+ References + Details

Leases (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Jan. 01, 2019

Dec. 31, 2018

Lease, Cost [Abstract]

Operating lease cost

$ 25

Short-term lease cost

Variable lease cost

Total lease cost

101

Operating lease income

Variable lease income

Total lease income

Assets and Liabilities, Lessee [Abstract]

Operating ROU assets (1)

^[1]

Total leased assets

$ 30

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

Total leased liabilities

$ 63

Weighted-average remaining lease term (in years) - operating leases

5 years 1 month 6 days

Weighted-average discount rate - operating leases

3.42%

Operating Lease Liabilities, Payments Due [Abstract]

$ 22

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

2019

^[4]

$ 6

^[4]

^[4]

^[4]

^[4]

^[4]

^[4]

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Total lease payments to be received

Other Information Related to Leases [Abstract]

Operating cash flows from operating leases included in the measurement of lease liabilities

Lessee Operating Lease Not Yet Commenced

Operating Leases, Lease Income [Abstract]

Lease, Cost [Abstract]

Operating lease cost

Short-term lease cost

Variable lease cost

Total lease cost

Operating lease income

Variable lease income

Total lease income

Assets and Liabilities, Lessee [Abstract]

Operating ROU assets (1)

^[1]

Total leased assets

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

Total leased liabilities

$ 1

Weighted-average remaining lease term (in years) - operating leases

5 years 2 months 12 days

Weighted-average discount rate - operating leases

3.52%

Operating Lease Liabilities, Payments Due [Abstract]

$ 1

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Total lease payments to be received

Other Information Related to Leases [Abstract]

Operating cash flows from operating leases included in the measurement of lease liabilities

Operating Leases, Lease Income [Abstract]

Lease, Cost [Abstract]

Operating lease cost

Short-term lease cost

Variable lease cost

Total lease cost

Operating lease income

Variable lease income

Total lease income

Assets and Liabilities, Lessee [Abstract]

Operating ROU assets (1)

^[1]

Total leased assets

$ 27

Current operating lease liability (2)

^[2]

Non-current operating lease liability (3)

^[3]

Total leased liabilities

$ 24

Weighted-average remaining lease term (in years) - operating leases

7 years 8 months 12 days

Weighted-average discount rate - operating leases

3.67%

Operating Lease Liabilities, Payments Due [Abstract]

$ 6

Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]

$ 32

Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]

Total lease payments to be received

Other Information Related to Leases [Abstract]

Operating cash flows from operating leases included in the measurement of lease liabilities

$ 6

[1]	Reported within Other assets in the Registrants’ respective Consolidated Balance Sheets.
[2]	Reported within Current other liabilities in the Registrants’ respective Consolidated Balance Sheets.
[3]	Reported within Other liabilities in the Registrants’ respective Consolidated Balance Sheets.
[4]	The Merger was completed on February 1, 2019. As such, these amounts are exclusive of Vectren’s leases.

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

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Weather hedges term

10 years

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

2019 to 2020 [Member] | Natural Gas Distribution [Member]

^[1]

$ 8

$ (4)

$ (1)

2019 to 2020 [Member] | Electric Transmission & Distribution [Member]

2019 to 2020 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

2019 to 2020 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission & Distribution [Member]

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

2018 to 2019 [Member] | Electric Transmission & Distribution [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] | Electric Transmission & Distribution [Member]

2017 to 2018 [Member] | Natural Gas Distribution [Member]

2017 to 2018 [Member] | Electric Transmission & Distribution [Member]

2017 to 2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

2017 to 2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission & Distribution [Member]

(2)

2016 to 2017 [Member] | Electric Transmission & Distribution [Member]

(2)

2016 to 2017 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission & Distribution [Member]

$ 0

(1)

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

Weather hedges term

10 years

CERC Corp [Member] | 2019 to 2020 [Member] | Natural Gas Distribution [Member]

^[1]

$ 2

(2)

CERC Corp [Member] | 2019 to 2020 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]

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

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

CERC Corp [Member] | 2017 to 2018 [Member] | Natural Gas Distribution [Member]

CERC Corp [Member] | 2017 to 2018 [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]

(2)

$ 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 Statements of Consolidated Income.
[2]	Relates to interest rate derivative instruments at SIGECO.

Reportable Segments Revenues by Products and Services (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Electric Delivery [Member]

$ 3,230

$ 2,742

$ 2,798

$ 3,531

$ 3,036

$ 2,212

$ 2,186

$ 3,155

$ 12,301

$ 10,589

$ 9,614

Retail Electric Sales [Member]

3,019

3,232

2,997

Wholesale Electric Sales [Member]

486

Retail Gas Sales [Member]

Wholesale Gas Sales [Member]

4,802

4,161

3,634

Gas Transportation and Processing [Member]

2,312

3,008

2,811

Energy Products and Services [Member]

1,186

449

156

143

Houston Electric [Member] | Electric Delivery [Member]

680

859

765

686

728

897

854

755

2,990

3,234

2,998

Houston Electric [Member] | Retail Gas Sales [Member]

2,990

3,234

2,998

Houston Electric [Member] | Wholesale Gas Sales [Member]

Houston Electric [Member] | Gas Transportation and Processing [Member]

Houston Electric [Member] | Energy Products and Services [Member]

CERC Corp [Member] | Electric Delivery [Member]

$ 1,734

$ 1,126

$ 1,342

$ 2,368

$ 2,303

^[1]

$ 1,312

^[1]

$ 1,328

^[1]

$ 2,400

^[1]

6,570

7,343

6,603

CERC Corp [Member] | Retail Gas Sales [Member]

CERC Corp [Member] | Wholesale Gas Sales [Member]

4,070

4,161

3,634

CERC Corp [Member] | Gas Transportation and Processing [Member]

2,313

3,008

2,811

CERC Corp [Member] | Energy Products and Services [Member]