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Cost of Goods and Services Sold

2,212

2,098

7,553

6,976

Expenses:

Utility natural gas

134

106

959

706

^[1]

864

832

2,927

2,843

Operation and maintenance

567

501

1,714

1,562

Taxes other than income taxes

326

269

982

749

307

288

1,986

1,801

6,889

6,148

Gain on marketable securities

226

297

664

828

Other Income (Expense):

104

Loss on indexed debt securities

(44)

(36)

(316)

(59)

Interest and other finance charges

(90)

(80)

(259)

(235)

Interest on Securitization Bonds

(16)

(18)

(46)

(58)

Equity in earnings of unconsolidated affiliate, net

208

199

Other, net

(1)

(2)

Income (Loss) Before Income Taxes

(17)

(30)

(331)

(51)

209

267

333

777

Income tax expense (benefit)

281

Net Income

158

169

248

496

Series A Preferred Stock dividend requirement

Income Available to Common Shareholders

$ 153

$ 169

$ 243

$ 496

Basic Earnings Per Common Share

$ 0.35

$ 0.39

$ 0.56

$ 1.15

Diluted Earnings Per Common Share

0.35

0.39

0.56

1.14

Dividends Declared Per Share

$ 0.2775

$ 0.2675

$ 0.5550

^[2]

$ 0.8025

Weighted Average Common Shares Outstanding, Basic

431,554,000

431,026,000

431,437,000

430,939,000

Weighted Average Common Shares Outstanding, Diluted

434,891,000

434,086,000

434,774,000

433,999,000

Revenues:

Operation and maintenance

$ 897

$ 843

$ 2,506

$ 2,233

Expenses:

369

337

1,062

1,021

Taxes other than income taxes

242

193

737

525

180

177

670

589

1,979

1,723

Interest and other finance charges

227

254

527

510

Other Income (Expense):

(32)

(101)

(97)

Interest on Securitization Bonds

(16)

(18)

(46)

(58)

Other, net

(3)

(6)

(9)

Income (Loss) Before Income Taxes

(48)

(53)

(153)

(164)

179

201

374

346

Income tax expense (benefit)

123

Net Income

143

130

296

223

Revenues:

Utility revenues

402

390

2,032

1,767

Non-utility revenues

910

861

3,008

2,964

Cost of Goods and Services Sold

1,312

1,251

5,040

4,731

Expenses:

Utility natural gas

134

106

959

706

864

832

2,927

2,843

Operation and maintenance

211

182

666

587

Taxes other than income taxes

222

202

120

104

1,319

1,220

4,894

4,442

Interest and other finance charges

(7)

146

289

Other Income (Expense):

(30)

(32)

(92)

Other, net

(4)

(5)

(13)

Income (Loss) Before Income Taxes

(30)

(36)

(97)

(105)

(37)

(5)

184

Income tax expense (benefit)

(2)

(1)

Income (Loss) From Continuing Operations

(35)

(4)

115

Income from discontinued operations (net of tax of $13, $26, $44 and $75, respectively)

140

124

Net Income

$ 9

$ 38

$ 175

$ 239

[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 Registrants for both the three and nine months ended September 30, 2018 and 2017, respectively.
[2]	On December 13, 2017, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of Common Stock, payable on March 8, 2018 to shareholders of record as of the close of business on February 15, 2018.

CONDENSED STATEMENTS OF CONSOLIDATED INCOME (Parentheticals) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
CERC Corp [Member]
Income tax expense associated with discontinued operations	$ 13	$ 26	$ 44	$ 75

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

Organization, Consolidation and Presentation of Financial Statements [Abstract]

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Net income	$ 158	$ 169	$ 248	$ 496
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans (net of tax of $1, $2, $2 and $4)	1	0	4	2
Net deferred gain (loss) from cash flow hedges (net of tax)	3	(2)	6	(3)
Total	4	(2)	10	(1)
Comprehensive income	162	167	258	495
Houston Electric [Member]
Net income	143	130	296	223
Other comprehensive income (loss):
Net deferred gain (loss) from cash flow hedges (net of tax)	3	0	7	(1)
Total	3	0	7	(1)
Comprehensive income	146	130	303	222
CERC Corp [Member]
Net income	9	38	175	239
Other comprehensive income (loss):
Net deferred gain (loss) from cash flow hedges (net of tax)	0	(1)	0	(1)
Comprehensive income	$ 9	$ 38	$ 175	$ 239

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Parentheticals) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Tax benefit (expense) on adjustment related to pension and postretirement plans	$ (1)	$ (2)	$ (2)	$ (4)
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	1	(2)	2	(2)
Houston Electric [Member]
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	$ 1	$ 0	$ 2	$ 0

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current Assets:
Cash and cash equivalents	$ 293	$ 260
Investment in marketable securities	627	960
Accounts receivable, less bad debt reserve	918	1,000
Accrued unbilled revenues	212	427
Natural gas inventory	207	222
Materials and supplies	198	175
Non-trading derivative assets	76	110
Taxes receivable	38	0
Prepaid expenses and other current assets	157	241
Total current assets	2,726	3,395
Property, Plant and Equipment:
Property, plant and equipment	19,861	19,031
Less: accumulated depreciation and amortization	6,208	5,974
Property, plant and equipment, net	13,653	13,057
Other Assets:
Goodwill	867	867
Regulatory assets	1,934	2,347
Non-trading derivative assets	38	44
Investment in unconsolidated affiliate	2,457	2,472
Preferred units – unconsolidated affiliate	363	363
Other	190	191
Total other assets	5,849	6,284
Total Assets	22,228	22,736
Current Liabilities:
Short-term borrowings	0	39
Current portion of VIE Securitization Bonds long-term debt	456	434
Indexed debt, net	25	122
Current portion of other long-term debt	50	50
Indexed debt securities derivative	685	668
Accounts payable	708	963
Taxes accrued	152	181
Interest accrued	80	104
Dividends accrued	0	120
Non-trading derivative liabilities	33	20
Other	392	368
Total current liabilities	2,581	3,069
Other Liabilities:
Deferred income taxes, net	3,220	3,174
Non-trading derivative liabilities	6	4
Benefit obligations	722	785
Regulatory liabilities	2,506	2,464
Other	433	357
Total other liabilities	6,887	6,784
Long-term Debt:
VIE Securitization Bonds, net	1,045	1,434
Other long-term debt, net	6,207	6,761
Total long-term debt, net	7,252	8,195
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized
Common stock	4	4
Additional paid-in capital	4,221	4,209
Retained earnings	551	543
Accumulated other comprehensive income (loss)	(58)	(68)
Total shareholders’ equity	5,508	4,688
Total Liabilities and Shareholders’ Equity	22,228	22,736
Houston Electric [Member]
Current Assets:
Cash and cash equivalents	279	238
Accounts and notes receivable, less bad debt reserve	389	284
Accounts and notes receivable–affiliated companies	13	7
Accrued unbilled revenues	122	120
Materials and supplies	129	119
Non-trading derivative assets	3	0
Taxes receivable	9	0
Prepaid expenses and other current assets	50	62
Total current assets	994	830
Property, Plant and Equipment:
Property, plant and equipment	11,962	11,496
Less: accumulated depreciation and amortization	3,742	3,633
Property, plant and equipment, net	8,220	7,863
Other Assets:
Regulatory assets	1,202	1,570
Other	20	29
Total other assets	1,222	1,599
Total Assets	10,436	10,292
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	456	434
Accounts payable	220	243
Accounts and notes payable–affiliated companies	113	104
Taxes accrued	88	116
Interest accrued	43	65
Other	111	120
Total current liabilities	1,031	1,082
Other Liabilities:
Deferred income taxes, net	1,044	1,059
Benefit obligations	142	146
Regulatory liabilities	1,265	1,263
Other	79	54
Total other liabilities	2,530	2,522
Long-term Debt:
VIE Securitization Bonds, net	1,045	1,434
Other long-term debt, net	3,281	2,885
Total long-term debt, net	4,326	4,319
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	1,696	1,696
Retained earnings	846	673
Accumulated other comprehensive income (loss)	7	0
Total shareholders’ equity	2,549	2,369
Total Liabilities and Shareholders’ Equity	10,436	10,292
CERC Corp [Member]
Current Assets:
Cash and cash equivalents	1	12
Accounts receivable, less bad debt reserve	527	713
Accounts and notes receivable–affiliated companies	9	6
Accrued unbilled revenues	90	307
Natural gas inventory	206	222
Materials and supplies	69	56
Non-trading derivative assets	73	110
Prepaid expenses and other current assets	85	166
Total current assets	1,060	1,592
Property, Plant and Equipment:
Property, plant and equipment	7,260	6,888
Less: accumulated depreciation and amortization	2,185	2,036
Property, plant and equipment, net	5,075	4,852
Other Assets:
Goodwill	867	867
Regulatory assets	170	181
Non-trading derivative assets	38	44
Investment in unconsolidated affiliate - discontinued operations	0	2,472
Other	95	104
Total other assets	1,170	3,668
Total Assets	7,305	10,112
Current Liabilities:
Short-term borrowings	0	39
Accounts payable	429	669
Accounts and notes payable–affiliated companies	44	611
Taxes accrued	64	75
Interest accrued	31	32
Customer deposits	74	76
Non-trading derivative liabilities	33	20
Other	171	137
Total current liabilities	846	1,659
Other Liabilities:
Deferred income taxes, net	370	362
Deferred income taxes, net - discontinued operations	0	927
Non-trading derivative liabilities	6	4
Benefit obligations	98	97
Regulatory liabilities	1,241	1,201
Other	350	297
Total other liabilities	2,065	2,888
Long-term Debt:
Total long-term debt, net	2,257	2,457
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	1,668	2,528
Retained earnings	463	574
Accumulated other comprehensive income (loss)	6	6
Total shareholders’ equity	2,137	3,108
Total Liabilities and Shareholders’ Equity	7,305	10,112
Series A Preferred Stock [Member]
Shareholders’ Equity:
Series A Preferred Stock, $0.01 par value, $800,000 aggregate liquidation preference, 800,000 shares outstanding	$ 790	$ 0

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
Cash and cash equivalents	$ 293,000,000	$ 260,000,000
Accounts receivable, less bad debt reserve	918,000,000	1,000,000,000
Bad debt reserve	15,000,000	19,000,000
Prepaid expenses and other current assets	157,000,000	241,000,000
Regulatory assets	$ 1,934,000,000	$ 2,347,000,000
Common stock par value (in dollars per share)	$ 0.01	$ 0.01
Common stock authorized (in shares)	1,000,000,000	1,000,000,000
Common stock outstanding (in shares)	431,555,853	431,044,845
Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	$ 278,000,000	$ 230,000,000
Accounts receivable, less bad debt reserve	92,000,000	73,000,000
Prepaid expenses and other current assets	37,000,000	35,000,000
Regulatory assets	1,146,000,000	1,590,000,000
Houston Electric [Member]
Cash and cash equivalents	279,000,000	238,000,000
Bad debt reserve	1,000,000	1,000,000
Prepaid expenses and other current assets	50,000,000	62,000,000
Regulatory assets	1,202,000,000	1,570,000,000
Houston Electric [Member] \| Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	278,000,000	230,000,000
Accounts receivable, less bad debt reserve	92,000,000	73,000,000
Prepaid expenses and other current assets	37,000,000	35,000,000
Regulatory assets	1,146,000,000	1,590,000,000
CERC Corp [Member]
Cash and cash equivalents	1,000,000	12,000,000
Accounts receivable, less bad debt reserve	527,000,000	713,000,000
Bad debt reserve	14,000,000	18,000,000
Prepaid expenses and other current assets	85,000,000	166,000,000
Regulatory assets	$ 170,000,000	$ 181,000,000
Cumulative Preferred Stock [Member]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Cumulative preferred stock authorized (in shares)	20,000,000	20,000,000
Series A Preferred Stock [Member]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0
Series A aggregate liquidation preference	$ 800,000	$ 0
Series A preferred stock outstanding (in shares)	800,000	0

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash Flows from Operating Activities:
Net income	$ 248	$ 496
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	982	749
Amortization of deferred financing costs	34	18
Deferred income taxes	33	185
Unrealized gain on marketable securities	(66)	(104)
Loss on indexed debt securities	316	59
Write-down of natural gas inventory	2	0
Equity in earnings of unconsolidated affiliate, net of distributions	(15)	(199)
Pension contributions	(67)	(46)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	355	216
Inventory	(10)	(52)
Taxes receivable	(38)	30
Accounts payable	(262)	(137)
Fuel cost recovery	53	(30)
Non-trading derivatives, net	63	(53)
Margin deposits, net	2	(49)
Interest and taxes accrued	(53)	2
Net regulatory assets and liabilities	44	(135)
Other current assets	11	18
Other current liabilities	16	19
Other assets	(3)	(3)
Other liabilities	24	28
Other, net	10	16
Net cash provided by operating activities	1,679	1,028
Cash Flows from Investing Activities:
Capital expenditures	(1,121)	(994)
Acquisitions, net of cash acquired	0	(132)
Distributions from unconsolidated affiliate in excess of cumulative earnings	30	223
Proceeds from sale of marketable securities	398	0
Other, net	19	6
Net cash used in investing activities	(674)	(897)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	(39)	13
Payments of commercial paper, net	(1,551)	(428)
Proceeds from long-term debt, net	997	1,096
Payments of long-term debt	(368)	(597)
Debt issuance costs	(36)	(13)
Payment of dividends on Common Stock	(360)	(346)
Proceeds from issuance of Series A Preferred Stock, net	790	0
Distribution to ZENS note holders	(398)	0
Other, net	(5)	(4)
Net cash used in financing activities	(970)	(279)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	35	(148)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	296	381
Cash, Cash Equivalents and Restricted Cash at End of Period	331	233
Cash and Cash Equivalents at Beginning of Period	260
Cash and Cash Equivalents at End of Period	293
Houston Electric [Member]
Cash Flows from Operating Activities:
Net income	296	223
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	737	525
Amortization of deferred financing costs	8	10
Deferred income taxes	(24)	29
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	(95)	(131)
Accounts receivable/payable–affiliated companies	(12)	(49)
Inventory	(10)	(3)
Taxes receivable	(9)	6
Accounts payable	(6)	105
Interest and taxes accrued	(50)	(28)
Net regulatory assets and liabilities	(66)	(149)
Other current assets	13	8
Other current liabilities	(9)	25
Other assets	4	1
Other liabilities	16	(1)
Other, net	(5)	(4)
Net cash provided by operating activities	788	567
Cash Flows from Investing Activities:
Capital expenditures	(678)	(603)
Decrease in notes receivable–affiliated companies	0	29
Other, net	15	5
Net cash used in investing activities	(663)	(569)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	398	298
Payments of long-term debt	(368)	(347)
Decrease in notes payable–affiliated companies	15	0
Dividend to parent	(123)	(87)
Debt issuance costs	(4)	(3)
Contribution from parent	0	0
Other, net	0	0
Net cash used in financing activities	(82)	(139)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	43	(141)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	274	381
Cash, Cash Equivalents and Restricted Cash at End of Period	317	240
Cash and Cash Equivalents at Beginning of Period	238
Cash and Cash Equivalents at End of Period	279
CERC Corp [Member]
Cash Flows from Operating Activities:
Net income	175	239
Less: Income from discontinued operations, net of tax	140	124
Income from continuing operations	35	115
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	222	202
Amortization of deferred financing costs	7	7
Deferred income taxes	6	69
Write-down of natural gas inventory	2	0
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	449	346
Accounts receivable/payable–affiliated companies	0	(1)
Inventory	1	(49)
Accounts payable	(261)	(227)
Fuel cost recovery	53	(30)
Non-trading derivatives, net	60	(51)
Margin deposits, net	2	(49)
Interest and taxes accrued	(9)	(13)
Net regulatory assets and liabilities	73	(28)
Other current assets	7	16
Other current liabilities	24	(5)
Other assets	5	5
Other liabilities	(2)	4
Other, net	0	1
Net cash provided by operating activities from continuing operations	674	312
Net cash provided by operating activities from discontinued operations	176	0
Net cash provided by operating activities	850	312
Cash Flows from Investing Activities:
Capital expenditures	(411)	(373)
Acquisitions, net of cash acquired	0	(132)
Other, net	5	2
Net cash used in investing activities from continuing operations	(406)	(503)
Net cash provided by investing activities from discontinued operations	47	223
Net cash used in investing activities	(359)	(280)
Cash Flows from Financing Activities:
Increase (decrease) in short-term borrowings, net	(39)	13
Payments of commercial paper, net	(800)	(40)
Proceeds from long-term debt, net	599	298
Decrease in notes payable–affiliated companies	(570)	0
Dividend to parent	(286)	(337)
Debt issuance costs	(5)	(4)
Contribution from parent	600	38
Other, net	(1)	0
Net cash used in financing activities from continuing operations	(502)	(32)
Net cash provided by financing activities from discontinued operations	0	0
Net cash used in financing activities	(502)	(32)
Net Decrease in Cash and Cash Equivalents	(11)	0
Cash and Cash Equivalents at Beginning of Period	12	1
Cash and Cash Equivalents at End of Period	$ 1	$ 1

Background and Basis of Presentation

9 Months Ended

Sep. 30, 2018

Background and Basis of Presentation [Text Block]

Background and Basis of Presentation

No Registrant makes any representations as to the information related solely to CenterPoint Energy or the subsidiaries of CenterPoint Energy other than itself.

General. Included in this combined Form 10-Q are the Interim Condensed Financial Statements of CenterPoint Energy, Houston Electric and CERC, which are referred to collectively as the Registrants. The Combined Notes to the Unaudited Condensed Consolidated Financial Statements apply to all Registrants unless otherwise indicated. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with each of the Registrants’ 2017 Form 10-K.

Background. CenterPoint Energy, Inc. is a public utility holding company and owns interests in Enable as described below. CenterPoint Energy’s operating subsidiaries, Houston Electric and CERC, own and operate electric transmission and distribution and natural gas distribution facilities and supply natural gas to commercial and industrial customers and electric and natural gas utilities.


•	Houston Electric engages in the electric transmission and distribution business 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 33 states through its wholly-owned subsidiary, CES.

As of September 30, 2018, CenterPoint Energy, indirectly through CNP Midstream, owned approximately 54.0% 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.

On September 4, 2018, CERC entered into a Contribution Agreement, by and between CERC and CNP Midstream, a new subsidiary formed by CERC in June 2018, pursuant to which CERC contributed its equity investment in Enable consisting of Enable common units and its interests in Enable GP, to CNP Midstream (collectively, the Enable Contribution). Immediately following the Enable Contribution, CERC distributed all of its interest in CNP Midstream to Utility Holding, CERC’s sole stockholder and a wholly-owned subsidiary of CenterPoint Energy. Utility Holding then distributed all of its interest in CNP Midstream to CenterPoint Energy, its sole member (collectively with the Enable Contribution, 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.

As a result of the Internal Spin, CERC’s equity in earnings in Enable and related income taxes have been classified as discontinued operations in CERC’s Interim Condensed Financial Statements. For further information regarding the Internal Spin and CERC’s presentation of discontinued operations, see Note 9.

As of September 30, 2018, 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 specifically 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 only payable from and secured by transition and system restoration property, and the bondholders have no recourse to the general credit of CenterPoint Energy or Houston Electric.

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

The Interim Condensed Financial Statements reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position, results of operations and cash flows for the respective periods. Amounts reported in the Condensed Statements of Consolidated Income are not necessarily indicative of amounts expected for a full-year period due to the effects of, among other things, (a) seasonal fluctuations in demand for energy and energy services, (b) changes in energy commodity prices, (c) timing of maintenance and other expenditures and (d) acquisitions and dispositions of businesses, assets and other interests. Certain prior year amounts have been reclassified to conform to the current year presentation. See Notes 2 and 9 for further discussion.

For a description of the Registrants’ reportable business segments, see Note 16.

New Accounting Pronouncements

9 Months Ended

Sep. 30, 2018

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements [Text Block]

New Accounting Pronouncements

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



Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2014-09- Revenue from Contracts with Customers (Topic 606) and related amendments	This standard provides a comprehensive new revenue recognition model that requires revenue to be recognized in a manner that depicts the transfer of goods or services to a customer at an amount that reflects the consideration expected to be received in exchange for those goods or services. Transition method: modified retrospective	January 1, 2018	Note 4 addresses the disclosure requirements. Adoption of the standard did not result in significant changes to revenue recognition. A substantial amount of the Registrants’ revenues are tariff and/or derivative based, which were not significantly impacted by these ASUs.
ASU 2017-05- Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets	This standard clarifies when and how to apply ASC 610-20, which was issued as part of ASU 2014-09. It amends or supersedes the guidance in ASC 350 and ASC 360 on determining a gain or loss recognized upon the derecognition of nonfinancial assets. Transition method: modified retrospective	January 1, 2018	ASU 2017-05 eliminates industry specific guidance, including ASC 360-20 Property, Plant, and Equipment - Real Estate Sales, for the recognition of gains or losses upon the sale of in-substance real estate. CenterPoint Energy and CERC elected to apply the practical expedient upon adoption to only evaluate transactions that were not determined to be complete as of the date of adoption. Subsequent to adoption, gains or losses on sales or dilution events in CenterPoint Energy’s investment in Enable may result in gains or losses recognized in earnings. See Note 9 for further discussion.
ASU 2016-01-Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities ASU 2018-03-Technical Corrections and Improvements to Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	This standard requires equity investments that do not result in consolidation and are not accounted for under the equity method to be measured at fair value and to recognize any changes in fair value in net income unless the investments qualify for the new practicability exception. It does not change the guidance for classifying and measuring investments in debt securities and loans. It also changes certain disclosure requirements and other aspects related to recognition and measurement of financial assets and financial liabilities. Transition method: cumulative-effect adjustment to beginning retained earnings, and two features prospective	January 1, 2018	The adoption of this standard did not have an impact on the Registrants’ financial position, results of operations or cash flows. The Registrants elected the practicability exception for investments without a readily determinable fair value to be measured at cost. This includes the Enable Series A Preferred Units owned by CenterPoint Energy, which were previously accounted for under the cost method. See Note 9 for further discussion.
ASU 2016-15- Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments	This standard provides clarifying guidance on the classification of certain cash receipts and payments in the statement of cash flows and eliminates the variation in practice related to such classifications. Transition method: retrospective	January 1, 2018	The adoption did not have a material impact on the Registrants’ financial position, results of operations or disclosures. However, CenterPoint Energy’s and Houston Electric’s Condensed Statements of Consolidated Cash Flows reflect an increase in investing activities and a corresponding decrease in operating activities of $1 million and $3 million for the nine months ended September 30, 2018 and 2017, respectively, due to the requirement that cash proceeds from COLI policies be classified as cash inflows from investing activity.



Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2016-18- Statement of Cash Flows (Topic 230): Restricted Cash	This standard requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, restricted cash and restricted cash equivalents. As a result, the statement of cash flows will no longer present transfers between cash and cash equivalents and restricted cash and restricted cash equivalents. When cash, cash equivalents, restricted cash and restricted cash equivalents are presented in more than one line item on the balance sheet, the new guidance requires a reconciliation of the totals in the statement of cash flows to the related captions in the balance sheet. Transition method: retrospective	January 1, 2018	The adoption of this standard did not have an impact on the Registrants’ financial position, results of operations or disclosures. However, CenterPoint Energy’s and Houston Electric’s Condensed Statements of Consolidated Cash Flows are reconciled to cash, cash equivalents and restricted cash, resulting in a decrease in investing activities of $2 million and an increase in investing activities of $8 million for the nine months ended September 30, 2018 and 2017, respectively. See Note 17 for further discussion.
ASU 2017-01- Business Combinations (Topic 805): Clarifying the Definition of a Business	This standard revises the definition of a business. If substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets, then under ASU 2017-01, the asset or group of assets is not a business. The guidance also requires a business to include at least one substantive process and narrows the definition of outputs to be more closely aligned with how outputs are described in ASC 606. Transition method: prospective	January 1, 2018	The adoption of this revised definition will reduce the number of transactions that are accounted for as a business combination, and therefore may have a potential impact on the Registrants’ accounting for future acquisitions.
ASU 2017-04- Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment	This standard eliminates Step 2 of the goodwill impairment test, which required a hypothetical purchase price allocation. A goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Transition method: prospective	January 1, 2018	The adoption of this standard will have an impact on CenterPoint Energy’s and CERC’s future calculation of goodwill impairments if an impairment is identified.
ASU 2017-07- Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost	This standard requires an employer to report the service cost component of the net periodic pension cost and postretirement benefit cost in the same line item(s) as other employee compensation costs arising from services rendered during the period; all other components will be presented separately from the line item(s) that includes the service cost and outside of any subtotal of operating income. In addition, only the service cost component will be eligible for capitalization in assets. Transition method: retrospective for the presentation of the service cost component and other components; prospective for the capitalization of the service cost component	January 1, 2018	The adoption of this standard did not have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures; however, it resulted in the increases to operating income and corresponding decreases to other income reported in the table below. Other components previously capitalized in assets will be recorded as regulatory assets in the Registrants’ rate-regulated businesses, prospectively.
ASU 2017-09- Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting	This standard clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as a modification. Entities will apply the modification accounting guidance if the value, vesting conditions or classification of the award changes. Transition method: prospective	January 1, 2018	The adoption of this standard will have an impact on CenterPoint Energy’s accounting for future changes to share-based payment awards.
ASU 2017-12- Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities	This standard expands an entity’s ability to hedge and account for risk components, reduces the complexity of applying certain aspects of hedge accounting and updates the presentation and disclosure requirements. The guidance eliminates the requirement to separately measure and report hedge ineffectiveness. Transition method: cumulative-effect adjustment for elimination of the separate measurement of ineffectiveness; prospective for presentation and disclosure	July 1, 2018 Applicable January 1, 2018	The adoption of this standard did not have a material impact on the Registrants’ financial position, results of operations or cash flows. As a result of the adoption, the Registrants will no longer recognize ineffectiveness for derivatives designated as cash flow hedges; all changes in fair value will flow through other comprehensive income. As the Registrants did not have existing cash flow hedges as of the initial application date and the adoption date, no cumulative effective adjustment was recorded. Note 7 reflects disclosures modified upon adoption.
ASU 2018-13- Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement	This standard eliminates, modifies and adds certain disclosure requirements for fair value measurements. Transition method: prospective for additions and one modification and retrospective for all other amendments	Adoption of eliminations and modifications as of September 30, 2018; Additions will be adopted January 1, 2020	The adoption of this standard did not impact the Registrants’ financial position, results of operations or cash flows. Note 8 reflects the disclosures modified upon adoption.

The table below reflects the impact of adoption of ASU 2017-07:



	Three Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	9	$	3	$	—	$	18	$	7	$	5
Decrease to other income	9		3		—		18		7		5
	Nine Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	38	$	18	$	8	$	52	$	22	$	16
Decrease to other income	38		18		8		52		22		16



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2016-02- Leases (Topic 842) and related amendments ASU 2018-01- Leases (Topic 842) Land Easement Practical Expedient for Transition to Topic 842 ASU 2018-10 - Codification Improvements to Topic 842, Leases ASU 2018-11- Leases (Topic 842)-Targeted Improvements	ASU 2016-02 provides a comprehensive new lease model that requires lessees to recognize assets and liabilities for most leases and would change certain aspects of lessor accounting. Transition method: modified retrospective ASU 2018-01 allows entities to elect not to assess whether existing land easements that were not previously accounted for in accordance with ASC 840 Leases under ASC 842 Leases when transitioning to the new leasing standard. ASU 2018-10 makes sixteen narrow-scope amendments to ASC 842 Leases. ASU 2018-11 allows entities the transition option to not apply the new lease standards in the comparative financial statements presented in the year of adoption. It also gives lessors the practical expedient to not separate non-lease and lease components when certain criteria are met.	January 1, 2019 Early adoption is permitted	The Registrants will elect the practical expedient on existing easements provided by ASU 2018-01, and the transition option to not apply the new lease standards in the comparative financial statements presented in the year of adoption provided by ASU 2018-11. The Registrants are evaluating other available transitional practical expedients. The Registrants are in the process of reviewing contracts to identify leases as defined in ASU 2016-02 and expect to recognize on the statements of financial position right-of-use assets and lease liabilities for the majority of their respective leases that are currently classified as operating leases. The Registrants are continuing to assess the impact that adoption of these standards will have on their financial position, results of operations, cash flows and disclosures.
ASU 2016-13- Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	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 starting January 1, 2019	The Registrants are currently assessing the impact that this standard will have on their financial position, results of operations, cash flows and disclosures.
ASU 2018-02-Income Statement-Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income	This standard allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA and requires entities to provide certain disclosures regarding stranded tax effects. Transition method: either in the period of adoption or retrospective	January 1, 2019 Early adoption is permitted	The adoption of this standard will allow the Registrants to reclass stranded deferred tax adjustments primarily related to benefit plans from other comprehensive income to retained earnings. The Registrants are currently assessing the impact that adoption of this standard will have on their financial position and disclosures.



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2018-14-Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans	This standard eliminates, modifies and adds certain disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Transition method: retrospective	January 1, 2021 Early adoption is permitted	The adoption of this standard will impact the Registrants’ annual disclosures and is not expected to have an impact on their financial position, results of operations, and cash flows. The Registrants are currently assessing the standard’s impact on the Stock-Based Incentive Compensation Plans and Employee Benefit Plans footnote.
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 allow the Registrants to capitalize certain implementation costs incurred in cloud computing arrangements that are accounted for as service contracts. The Registrants are currently assessing the impact that adoption of this standard will have on their financial position, results of operations, cash flows and 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.

Pending Merger with Vectren (CenterPoint Energy)	9 Months Ended
Pending Merger with Vectren (CenterPoint Energy)	Sep. 30, 2018
Business Combinations [Abstract]
Pending Merger with Vectren (CenterPoint Energy) [Text Block]	Pending Merger with Vectren (CenterPoint Energy) On April 21, 2018, CenterPoint Energy entered into the Merger Agreement. Under the terms of the Merger Agreement, CenterPoint Energy will acquire Vectren for approximately $6 billion in cash. Upon closing, Vectren will become a wholly-owned subsidiary of CenterPoint Energy. Pursuant to the Merger Agreement, upon the closing of the Merger, each share of Vectren common stock issued and outstanding immediately prior to the closing will be converted automatically into the right to receive $72.00 in cash per share. During August and October 2018, CenterPoint Energy completed its permanent financing for the Merger through offerings of the Series A Preferred Stock, depositary shares, each representing a 1/20th interest in a share of Series B Preferred Stock, Common Stock and unsecured senior notes. See Notes 12 and 19 for further details regarding the Merger financings. As of September 30, 2018, Vectren and its subsidiaries had outstanding $325 million of short-term debt and $2.0 billion of long-term debt, including current maturities. It is anticipated that Vectren and its subsidiaries will have approximately $2.5 billion of outstanding short-term and long-term debt as of December 31, 2018. Consummation of the Merger is conditioned upon approval by federal regulatory commissions, orders from state regulatory commissions, expiration or termination of the applicable HSR waiting period and approval of the Merger by Vectren shareholders. In June 2018, CenterPoint Energy and Vectren (i) submitted their filings with the FERC and the FCC, (ii) submitted their filings with the FTC pursuant to the HSR Act and (iii) initiated informational proceedings with regulators in Indiana and Ohio. On June 26, 2018, CenterPoint Energy and Vectren received notice from the FTC granting early termination of the waiting period under the HSR Act in connection with the Merger. On August 28, 2018, shareholders of Vectren, during a special shareholders’ meeting, approved the Merger. The FCC granted approvals on July 20 and 24, 2018, and on October 5, 2018, the FERC authorized the Merger. A hearing before the Indiana Utility Regulatory Commission was held on October 17, 2018 with respect to the Merger. CenterPoint Energy has requested a final order for this proceeding by the end of January or early February 2019. The Merger Agreement contains termination rights for both CenterPoint Energy and Vectren, and provides that, upon termination of the Merger Agreement under specified circumstances, CenterPoint Energy would be required to pay a termination fee of $210 million to Vectren or Vectren would be required to pay CenterPoint Energy a termination fee of $150 million. Subject to receipt of required regulatory and statutory approvals and satisfaction and/or waiver of the closing conditions, CenterPoint Energy continues to anticipate closing the Merger in the first quarter of 2019.

Revenue Recognition

9 Months Ended

Sep. 30, 2018

Revenue from Contract with Customer [Abstract]

Revenue Recognition [Text Block]

Revenue Recognition

The Registrants adopted ASC 606 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. Contract assets and liabilities are not material.

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

CenterPoint Energy



	Three Months Ended September 30,
	2018														2017
	Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total
	(in millions)
Revenue from contracts	$	904		$	398		$	82		$	1	$	1,385		$	852		$	396		$	97		$	2	$	1,347
Derivatives income	—			—			838			—		838			—			—			774			—		774
Other (3)	(7		)	12			—			2		7			(9		)	2			—			2		(5		)
Eliminations	—			(8		)	(10		)	—		(18		)	—			(8		)	(10		)	—		(18		)
Total revenues	$	897		$	402		$	910		$	3	$	2,212		$	843		$	390		$	861		$	4	$	2,098

	Nine Months Ended September 30,
	2018														2017
	Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total
	(in millions)
Revenue from contracts	$	2,525		$	2,093		$	338		$	4	$	4,960		$	2,254		$	1,784		$	355		$	4	$	4,397
Derivatives income	(4		)	—			2,727			—		2,723			1			—			2,643			—		2,644
Other (3)	(19		)	(35		)	—			7		(47		)	(21		)	7			—			7		(7		)
Eliminations	—			(26		)	(57		)	—		(83		)	—			(24		)	(34		)	—		(58		)
Total revenues	$	2,502		$	2,032		$	3,008		$	11	$	7,553		$	2,234		$	1,767		$	2,964		$	11	$	6,976

Houston Electric



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Revenue from contracts	$	904		$	852		$	2,525		$	2,254
Other (3)	(7		)	(9		)	(19		)	(21		)
	$	897		$	843		$	2,506		$	2,233

CERC



	Three Months Ended September 30,
	2018									2017
	Natural Gas Distribution (1)			Energy Services (2)			Total			Natural Gas Distribution (1)			Energy Services (2)			Total
	(in millions)
Revenue from contracts	$	398		$	82		$	480		$	396		$	97		$	493
Derivatives income	—			838			838			—			774			774
Other (3)	12			—			12			2			—			2
Eliminations	(8		)	(10		)	(18		)	(8		)	(10		)	(18		)
Total revenues	$	402		$	910		$	1,312		$	390		$	861		$	1,251

	Nine Months Ended September 30,
	2018									2017
	Natural Gas Distribution (1)			Energy Services (2)			Total			Natural Gas Distribution (1)			Energy Services (2)			Total
	(in millions)
Revenue from contracts	$	2,093		$	338		$	2,431		$	1,784		$	355		$	2,139
Derivatives income	—			2,727			2,727			—			2,643			2,643
Other (3)	(35		)	—			(35		)	7			—			7
Eliminations	(26		)	(57		)	(83		)	(24		)	(34		)	(58		)
Total revenues	$	2,032		$	3,008		$	5,040		$	1,767		$	2,964		$	4,731


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


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

(3)

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

Revenues from Contracts with Customers

Electric Transmission & Distribution. 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.

Natural Gas Distribution. 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. 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.

Practical Expedients and Exemption. Sales taxes and other similar taxes collected from customers are excluded from the transaction price.

Employee Benefit Plans

9 Months Ended

Sep. 30, 2018

Retirement Benefits [Abstract]

Employee Benefit Plans [Text Block]

Employee Benefit Plans

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

Pension Benefits (CenterPoint Energy)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Service cost (1)	$	10		$	9		$	28		$	27
Interest cost (2)	20			22			59			66
Expected return on plan assets (2)	(27		)	(24		)	(80		)	(72		)
Amortization of prior service cost (2)	3			2			7			7
Amortization of net loss (2)	10			14			32			43
Net periodic cost	$	16		$	23		$	46		$	71

Postretirement Benefits



	Three Months Ended September 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	—		$	—		$	1		$	—		$	—		$	1
Interest cost (2)	3			2			1			4			3			1
Expected return on plan assets (2)	(1		)	(1		)	—			(1		)	(1		)	(1		)
Amortization of prior service credit (2)	(1		)	(1		)	—			(1		)	(2		)	—
Net periodic cost	$	1		$	—		$	2		$	2		$	—		$	1

	Nine Months Ended September 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	1		$	1		$	—		$	1
Interest cost (2)	10			6			3			12			7			3
Expected return on plan assets (2)	(4		)	(3		)	(1		)	(4		)	(3		)	(1		)
Amortization of prior service cost (credit) (2)	(3		)	(4		)	1			(3		)	(4		)	1
Net periodic cost (credit)	$	4		$	(1	)	$	4		$	6		$	—		$	4


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


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

Changes in accumulated other comprehensive loss related to defined benefit and postretirement plans are as follows:

CenterPoint Energy



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Beginning Balance	$	(63	)	$	(70	)	$	(66	)	$	(72	)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	—			—			1			1
Actuarial losses (1)	2			2			5			5
Tax expense	(1		)	(2		)	(2		)	(4		)
Net current period other comprehensive income	1			—			4			2
Ending Balance	$	(62	)	$	(70	)	$	(62	)	$	(70	)


(1)	These accumulated other comprehensive components are included in the computation of net periodic cost.

The table below reflects the expected contributions to be made to the pension plans and postretirement benefit plan during 2018:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2018	$	67	$	—	$	—
Expected contribution to postretirement benefit plan in 2018	16		10		5

The table below reflects the contributions made to the pension plans and postretirement benefit plan during 2018:



	Three Months Ended September 30, 2018						Nine Months Ended September 30, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	3	$	—	$	—	$	67	$	—	$	—
Postretirement benefit plan	4		3		1		11		7		3

Regulatory Accounting

9 Months Ended

Sep. 30, 2018

Regulatory Assets and Liabilities, Other Disclosures [Abstract]

Regulatory Accounting [Text Block]

Regulatory Accounting

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



	September 30, 2018									December 31, 2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	60		$	—		$	60		$	130		$	—		$	130
Non-current regulatory assets:
Securitized regulatory assets	1,146			1,146			—			1,590			1,590			—
Unrecognized equity return (2)	(225		)	(225		)	—			(287		)	(287		)	—
Unamortized loss on reacquired debt	70			70			—			75			75			—
Pension and postretirement-related regulatory asset (3)	609			32			15			646			31			20
Hurricane Harvey restoration costs (4)	67			61			6			64			58			6
Regulatory assets related to TCJA (5)	48			34			14			48			33			15
Other long-term regulatory assets (6)	219			84			135			211			70			140
Total non-current regulatory assets	1,934			1,202			170			2,347			1,570			181
Total regulatory assets	1,994			1,202			230			2,477			1,570			311
Regulatory Liabilities:
Current regulatory liabilities (7)	47			22			25			24			22			2
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (5)	1,362			858			504			1,354			862			492
Estimated removal costs	887			275			612			878			285			593
Other long-term regulatory liabilities	257			132			125			232			116			116
Total non-current regulatory liabilities	2,506			1,265			1,241			2,464			1,263			1,201
Total regulatory liabilities	2,553			1,287			1,266			2,488			1,285			1,203
Total regulatory assets and liabilities, net	$	(559	)	$	(85	)	$	(1,036	)	$	(11	)	$	285		$	(892	)


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

(2)

The unrecognized equity return will be recognized as it is recovered in rates through 2024. During the three months ended September 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $17 million and $13 million, respectively, of the allowed equity return. During the nine months ended September 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $62 million and $30 million, respectively, of the allowed equity return. 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.


(3)	Includes a portion of NGD’s actuarially determined pension and other postemployment expense in excess of the amount being recovered through rates that is being deferred for rate making purposes, of which $4 million and $7 million as of September 30, 2018 and December 31, 2017, respectively, were not earning a return.


(4)	The Registrants are not earning a return on Hurricane Harvey restoration costs.


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


(6)	Other long-term regulatory assets that are not earning a return were not material as of September 30, 2018 and December 31, 2017.


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

Derivative Instruments

9 Months Ended

Sep. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments [Text Block]

Derivative Instruments

The Registrants are exposed to various market risks. These risks arise from transactions entered into in the normal course of business. The Registrants utilize derivative instruments such as physical forward contracts, swaps and options to mitigate the impact of changes in commodity prices, weather and interest rates on its operating results and cash flows. Such derivatives are recognized in the Registrants’ Condensed Consolidated Balance Sheets at their fair value unless the Registrants elect 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 has a Risk Oversight Committee composed of corporate and business 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’ commercial risk management policy 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.


(a)	Non-Trading Activities

Commodity Derivative Instruments. CenterPoint Energy 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 business segment are designated as fair value hedges for accounting purposes. All other financial instruments do not qualify or are not designated as cash flow or fair value hedges.

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

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 does not enter into weather hedges.

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



				Three Months Ended September 30,				Nine Months Ended September 30,
Jurisdiction	Winter Season	Bilateral Cap		2018		2017		2018			2017
		(in millions)
Certain NGD jurisdictions	2018 – 2019	$	9	$	—	$	—	$	—		$	—
Certain NGD jurisdictions	2017 – 2018	8		—		—		—			—
Total CERC (1)				—		—		—			—
Electric operations’ service territory	2018 – 2019	8		—		—		—			—
Electric operations’ service territory	2017 – 2018	9		—		—		(4		)	—
Electric operations’ service territory	2016 – 2017	9		—		—		—			1
Total CenterPoint Energy (1)				$	—	$	—	$	(4	)	$	1


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

Cash Flow Hedging of Interest Expense. From time to time, the Registrants enter into forward interest rate agreements with certain counterparties designated as cash flow hedges. The objective of these cash flow hedges is to reduce exposure to variability in cash flows related to interest payments on anticipated future fixed rate debt offerings or other exposure to variable rate debt. In October 2018, Houston Electric entered into an additional $100 million of notional amount on forward interest rate agreements classified as cash flow hedges. As of September 30, 2018 and December 31, 2017, the total outstanding notional amount of Houston Electric’s forward interest rate agreements related to cash flow hedges was $100 million and $-0-, respectively. The maximum length of time over which Houston Electric is exposed to the variability in future cash flows of the forecasted debt offerings is less than 12 months.

Economic Hedging of Interest Rate Risk. From time to time, the Registrants may enter into forward interest rate agreements with certain counterparties designated as economic hedges. The objective of these economic hedges is to offset any interest rate risk borne by one or more of the Registrants in connection with an anticipated future fixed rate debt offering or other exposure to variable rate debt. As of September 30, 2018 and December 31, 2017, the total outstanding notional amount of CenterPoint Energy’s forward interest rate agreements related to economic hedges in connection with the permanent financing for the Merger was $200 million and $-0-, respectively. As of September 30, 2018 and December 31, 2017, the fair value of interest rate derivatives was less than $1 million and therefore was not included in the tabular presentation below.


(b)	Derivative Fair Values and Income Statement Impacts

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

Fair Value of Derivative Instruments and Hedged Items



		September 30, 2018				December 31, 2017
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
Derivatives designated as cash flow hedges:		(in millions)
Interest rate derivatives	Current Assets: Non-trading derivative assets	$	3	$	—	$	—	$	—
Total Houston Electric		3		—		—		—
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	—		2		13		1
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	76		3		114		4
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	38		—		44		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	31		72		38		78
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	16		33		9		24
Total CERC		161		110		218		107
Indexed debt securities derivative	Current Liabilities	—		685		—		668
Total CenterPoint Energy		$	164	$	795	$	218	$	775


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,865 Bcf or a net 310 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of September 30, 2018 and December 31, 2017, 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 the Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities was a $72 million asset and a $130 million asset as of September 30, 2018 and December 31, 2017, respectively, as shown on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets (and as detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $21 million and $19 million, respectively.


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

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



		September 30, 2018				December 31, 2017
	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
Hedged items in fair value hedge relationship:		(in millions)
Natural gas inventory	Current Assets: Natural gas inventory	$	39	$	1	$	80	$	14
Total CenterPoint Energy and CERC		$	39	$	1	$	80	$	14

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



	September 30, 2018									December 31, 2017
	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	$	107		$	(34	)	$	73		$	165		$	(55	)	$	110
Other Assets: Non-trading derivative assets	54			(16		)	38			53			(9		)	44
Current Liabilities: Non-trading derivative liabilities	(77		)	44			(33		)	(83		)	63			(20		)
Other Liabilities: Non-trading derivative liabilities	(33		)	27			(6		)	(24		)	20			(4		)
Total	$	51		$	21		$	72		$	111		$	19		$	130


(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 Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

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



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (2)
	Non-utility natural gas expense						Non-utility natural gas expense
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	864		$	832		$	2,927		$	2,843

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	1			4			(13		)	(10		)
Derivatives designated as hedging instruments	(1		)	(4		)	13			10
Amounts excluded from effectiveness testing recognized in earnings immediately (1)	6			(9		)	(73		)	(93		)

(1)

As a result of the adoption of ASU 2017-12 effective January 1, 2018 (see Note 2 for additional information), CenterPoint Energy and CERC exclude from their assessment of hedge effectiveness the natural gas market price difference between locations of the hedged inventory and the delivery location specified in the hedge instruments. Prior to the adoption of this accounting guidance, the timing difference between the spot price and the futures price, as well as the difference between the timing of the settlement of the futures and the valuation of the underlying physical commodity, was excluded from the assessment of effectiveness for CenterPoint Energy’s and CERC’s existing fair value hedges and will continue to be excluded from the assessment of hedge effectiveness. CenterPoint Energy and CERC elected to continue to immediately recognize amounts excluded from hedge effectiveness in their respective Condensed Statements of Consolidated Income.


(2)	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 Registrants for both the three and nine months ended September 30, 2018 and 2017, respectively.



		Three Months Ended September 30,						Nine Months Ended September 30,
	Income Statement Location	2018			2017			2018			2017
Effects of derivatives not designated as hedging instruments on the income statement:		(in millions)
Commodity contracts	Gains (Losses) in Non-utility revenues	$	2		$	30		$	70		$	162
Total CERC		2			30			70			162
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(44		)	(36		)	(316		)	(59		)
Interest rate derivatives	Gains (Losses) in Interest and other finance charges	—			—			—			—
Total CenterPoint Energy		$	(42	)	$	(6	)	$	(246	)	$	103

Effect of Cash Flow Hedge Accounting on Accumulated Other Comprehensive Income



	Amount of Gain (Loss) Recognized in Other Comprehensive Income, Net of Tax on Derivative
	Three Months Ended September 30,					Nine Months Ended September 30,
	2018		2017			2018			2017
	(in millions)
Effects of cash flow hedging
Interest rate derivatives (1)	$	3	$	—		$	7		$	(1	)
Total Houston Electric	3		—			7			(1		)
Interest rate derivatives (1)	—		(1		)	—			(1		)
Total CERC	—		(1		)	—			(1		)
Interest rate derivatives (1)	—		(1		)	(1		)	(1		)
Total CenterPoint Energy	$	3	$	(2	)	$	6		$	(3	)

(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 the Condensed Statements of Consolidated Income. Amounts are less than $1 million for each of the three and nine months ended September 30, 2018 and 2017. Over the next twelve months, estimated amortization of accumulated other comprehensive income into related income is expected to be immaterial.


(c)	Credit Risk Contingent Features

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.

CenterPoint Energy and CERC



	September 30, 2018		December 31, 2017
	(in millions)
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position	$	2	$	2
Fair value of collateral already posted	—		—
Additional collateral required to be posted if credit risk contingent features triggered	1		2

Fair Value Measurements

9 Months Ended

Sep. 30, 2018

Fair Value Disclosures [Abstract]

Fair Value Measurements [Text Block]

Fair Value Measurements

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

Level 1: Inputs are unadjusted quoted prices in active markets for identical assets or liabilities at the measurement date. The types of assets carried at Level 1 fair value generally are exchange-traded derivatives and equity securities, as well as natural gas inventory that has been designated as the hedged item in a fair value hedge.

Level 2: Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, 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 September 30, 2018, 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 include illiquid forward price curve locations (ranging from $1.28 to $6.88 per MMBtu) as an unobservable input. CenterPoint Energy’s and CERC’s Level 3 physical natural gas forward contracts and options derivative assets and liabilities consist of both long and short positions (forwards and options). Forward price decreases (increases) as of September 30, 2018 would have resulted in lower (higher) values, respectively, for long forwards and options and higher (lower) values, respectively, for short forwards and options.

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

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

CenterPoint Energy



	September 30, 2018											December 31, 2017
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	630	$	—	$	—	$	—		$	630	$	963	$	—	$	—	$	—		$	963
Investments, including money market funds (2)	70		—		—		—			70		68		—		—		—			68
Interest rate derivatives	3		—		—		—			3		—		—		—		—			—
Natural gas derivatives (3)	—		134		27		(50		)	111		—		161		57		(64		)	154
Hedged portion of natural gas inventory	1		—		—		—			1		14		—		—		—			14
Total assets	$	704	$	134	$	27	$	(50	)	$	815	$	1,045	$	161	$	57	$	(64	)	$	1,199
Liabilities
Indexed debt securities derivative	$	—	$	685	$	—	$	—		$	685	$	—	$	—	$	668	$	—		$	668
Natural gas derivatives (3)	—		105		5		(71		)	39		—		96		11		(83		)	24
Total liabilities	$	—	$	790	$	5	$	(71	)	$	724	$	—	$	96	$	679	$	(83	)	$	692

Houston Electric



	September 30, 2018										December 31, 2017
	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)	$	52	$	—	$	—	$	—	$	52	$	51	$	—	$	—	$	—	$	51
Interest rate derivatives	3		—		—		—		3		—		—		—		—		—
Total assets	$	55	$	—	$	—	$	—	$	55	$	51	$	—	$	—	$	—	$	51

CERC



	September 30, 2018											December 31, 2017
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	3	$	—	$	—	$	—		$	3	$	3	$	—	$	—	$	—		$	3
Investments, including money market funds (2)	10		—		—		—			10		11		—		—		—			11
Natural gas derivatives (3)	—		134		27		(50		)	111		—		161		57		(64		)	154
Hedged portion of natural gas inventory	1		—		—		—			1		14		—		—		—			14
Total assets	$	14	$	134	$	27	$	(50	)	$	125	$	28	$	161	$	57	$	(64	)	$	182
Liabilities
Natural gas derivatives (3)	$	—	$	105	$	5	$	(71	)	$	39	$	—	$	96	$	11	$	(83	)	$	24
Total liabilities	$	—	$	105	$	5	$	(71	)	$	39	$	—	$	96	$	11	$	(83	)	$	24


(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 of $21 million and $19 million as of September 30, 2018 and December 31, 2017, respectively, posted with the same counterparties.


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


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

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



	Three Months Ended September 30,												Nine Months Ended September 30,
	2018						2017						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	(628	)	$	13		$	(712	)	$	28		$	(622	)	$	46		$	(704	)	$	13
Total gains (losses)	1			1			(38		)	(2		)	4			4			(38		)	21
Total settlements	(1		)	(1		)	(1		)	(1		)	(36		)	(36		)	(5		)	(5		)
Transfers into Level 3	—			—			7			7			(2		)	(2		)	9			9
Transfers out of Level 3 (1)	650			9			(6		)	(6		)	678			10			(12		)	(12		)
Ending balance (2)	$	22		$	22		$	(750	)	$	26		$	22		$	22		$	(750	)	$	26

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:
	$	11		$	11		$	(36	)	$	—		$	9		$	9		$	(42	)	$	17


(1)	As of September 30, 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 sales or purchases during either of the three or nine months ended September 30, 2018 or 2017.

Estimated Fair Value of Financial Instruments

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



	September 30, 2018						December 31, 2017
	CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	(in millions)
Carrying amount	$	7,758	$	4,782	$	2,257	$	8,679	$	4,753	$	2,457
Fair value	7,888		4,813		2,367		9,220		5,034		2,708


(1)	Includes Securitization Bond debt.

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

Equity Method Investments and Joint Ventures [Abstract]

Unconsolidated Affiliate (CenterPoint Energy and CERC)

9 Months Ended

Sep. 30, 2018

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

Unconsolidated Affiliate (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, account for the investment in Enable’s common units using the equity method of accounting. Upon the adoption of ASU 2014-09 and ASU 2017-05 on January 1, 2018, CenterPoint Energy evaluated transactions in the investment in Enable that occurred prior to January 1, 2018 (the effective date) and concluded a cumulative effect adjustment to the opening balance of retained earnings was not required. See Note 2 for further discussion.

CenterPoint Energy’s maximum exposure to loss related to Enable, a VIE in which CenterPoint Energy is not the primary beneficiary, is limited to the equity investment, the Series A Preferred Unit investment and outstanding current accounts receivable from Enable.

On September 4, 2018, CERC completed the Internal Spin of its equity investment in Enable and Enable GP. The Internal Spin has been accounted for under the guidance for transactions between entities under common control. As of September 4, 2018, CERC derecognized its investment in Enable at carrying value on the date of distribution of $2.4 billion, net of deferred income taxes of $974 million, and CNP Midstream recorded the net asset contribution from CERC at CERC’s carrying value. Neither CERC nor CNP Midstream recognized a gain or loss upon the distribution or contribution, respectively, of net assets involved in the Internal Spin. In connection with the Internal Spin, CenterPoint Energy, through Utility Holding, made a $600 million capital contribution to CERC, which was used by CERC to repay outstanding indebtedness that historically supported CERC’s legacy midstream assets. See Note 18 for further discussion.

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



	September 30, 2018
	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)
CenterPoint Energy (3)	54.0	%	233,856,623	14,520,000
OGE	25.6	%	110,982,805	—
Public unitholders	20.4	%	88,376,728	—
Total units outstanding	100.0	%	433,216,156	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 Condensed Consolidated Balance Sheets, was $363 million as of both September 30, 2018 and December 31, 2017. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods. See Note 2 for further discussion.


(3)	Includes Enable Series A Preferred Units held directly by CenterPoint Energy and common units held indirectly through CNP Midstream.

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

Interests Held in Enable GP (CenterPoint Energy):



	September 30, 2018
	Management Rights (1)		Incentive Distribution Rights (2)
CenterPoint Energy (3)	50	%	40	%
OGE	50	%	60	%


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

(2)

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


(3)	Includes interests held through CNP Midstream.

Distributions Received from Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Investment in Enable common units (1)	$	74	$	74	$	223	$	223
Total CERC (2)	74		74		223		223
Investment in Enable Series A Preferred Units (3)	9		9		27		27
Total CenterPoint Energy	$	83	$	83	$	250	$	250


(1)	Reflects cash distributions of $0.318 and $0.954 per common unit for the three and nine months ended September 30, 2018 and 2017, respectively.


(2)	On September 4, 2018, CERC completed the Internal Spin. After such date, CNP Midstream owned the Enable common units previously owned by CERC.


(3)	Reflects cash distributions of $0.625 and $1.875 per Enable Series A Preferred Unit for the three and nine months ended September 30, 2018 and 2017, respectively.

Transactions with Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Reimbursement of transition services (1) (CenterPoint Energy)	$	1	$	—	$	4	$	3
Natural gas expenses, including transportation and storage costs (CenterPoint Energy and CERC)	23		23		89		80


(1)	Represents amounts billed under the Transition Agreements for certain support services provided to Enable. Actual transition services costs are recorded net of reimbursement.



	September 30, 2018		December 31, 2017
	(in millions)
Accounts receivable for amounts billed for transition services (CenterPoint Energy)	$	3	$	1
Accounts payable for natural gas purchases from Enable (CenterPoint Energy and CERC)	8		13

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Operating revenues	$	928	$	705	$	2,481	$	1,997
Cost of sales, excluding depreciation and amortization	516		349		1,335		936
Depreciation and amortization	100		90		292		267
Operating income	171		137		436		399
Net income attributable to Enable common units	129		104		320		301
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	70	$	56	$	173	$	163
Basis difference amortization (1)	11		12		35		36
CenterPoint Energy’s equity in earnings, net	$	81	$	68	$	208	$	199

(1)

Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s original investment in Enable and their underlying equity in Enable’s net assets. The basis difference is amortized over approximately 31 years, the average life of the assets to which the basis difference is attributed.

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



	September 30, 2018			December 31, 2017
	(in millions)
Current assets	$	481		$	416
Non-current assets	11,454			11,177
Current liabilities	1,403			1,279
Non-current liabilities	2,964			2,660
Non-controlling interest	11			12
Preferred equity	362			362
Enable partners’ equity	7,195			7,280
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,883		$	3,935
CenterPoint Energy’s basis difference	(1,426		)	(1,463		)
CenterPoint Energy’s equity method investment in Enable	$	2,457		$	2,472

Discontinued Operations (CERC):

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 Condensed 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 Condensed Consolidated Balance Sheets for the periods presented. The following table presents amounts included in Income from discontinued operations, net of tax in CERC’s Condensed Statements of Consolidated Income.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Equity in earnings of unconsolidated affiliate, net	$	57	$	68	$	184	$	199
Income tax expense	13		26		44		75
Income from discontinued operations, net of tax	$	44	$	42	$	140	$	124

Goodwill and Other Intangibles (CenterPoint Energy and CERC)

9 Months Ended

Sep. 30, 2018

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 and CERC’s goodwill by reportable business segment as of both September 30, 2018 and December 31, 2017 is as follows:



	(in millions)
Natural Gas Distribution	$	746
Energy Services (1)	110
Other Operations	11
Total	$	867

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

CenterPoint Energy and CERC perform goodwill impairment tests at least annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. The impairment evaluation for goodwill is performed by comparing the fair value of each reporting unit with the carrying amount of the reporting unit, including goodwill. The estimated fair value of the reporting unit is primarily determined on the basis of discounted cash flows. If the carrying amount is in excess of the estimated fair value of the reporting unit, then the excess amount is the impairment charge that should be recorded, not to exceed the carrying amount of goodwill. See Note 2 for further discussion.

CenterPoint Energy and CERC performed the annual goodwill impairment test in the third quarter of 2018 and determined that no goodwill impairment charge was required for any reporting unit, which approximate the reportable segments.

The tables below present information on CenterPoint Energy’s and CERC’s other intangible assets recorded in Other non-current assets on the Condensed Consolidated Balance Sheets.



		September 30, 2018							December 31, 2017
	Useful Lives	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in years)	(in millions)
Customer relationships	15	$	86	$	(26	)	$	60	$	86	$	(21	)	$	65
Covenants not to compete	4	4		(2		)	2		4		(2		)	2
Other	Various	15		(10		)	5		15		(8		)	7
Total		$	105	$	(38	)	$	67	$	105	$	(31	)	$	74



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Amortization expense of intangible assets	$	2	$	2	$	7	$	5

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

Investments, Debt and Equity Securities [Abstract]

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

9 Months Ended

Sep. 30, 2018

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

In 1995, CenterPoint Energy sold a cable television subsidiary to TW and received certain TW securities as partial consideration. A subsidiary of CenterPoint Energy holds shares of certain securities detailed in the table below, which are classified as trading securities and are expected to be held to facilitate CenterPoint Energy’s ability to meet its obligation under the ZENS. Unrealized gains and losses resulting from changes in the market value of the ZENS-Related Securities are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income.



	Shares Held
	September 30, 2018	December 31, 2017
AT&T Common	10,212,945	—
Charter Common	872,503	872,503
Time Common	—	888,392
TW Common	—	7,107,130

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1 billion of which $828 million remain outstanding as of September 30, 2018. Each ZENS was originally 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 of TW Common attributable to such note. The number and identity of the reference shares attributable to each ZENS are adjusted for certain corporate events.

On October 22, 2016, AT&T announced that it had entered into a definitive agreement to acquire TW in a stock and cash transaction. On February 15, 2017, TW shareholders approved the announced transaction with AT&T. The merger closed on June 14, 2018. CenterPoint Energy received $53.75 and 1.437 shares of AT&T Common for each share of TW Common held, resulting in cash proceeds of $382 million and 10,212,945 shares of AT&T Common. In accordance with the terms of the ZENS, CenterPoint Energy remitted $382 million to ZENS note holders in July 2018, which reduced the contingent principal amount.

On November 26, 2017, Meredith announced that it had entered into a definitive merger agreement with Time. Pursuant to the merger agreement, upon closing of the merger, a subsidiary of Meredith would purchase for cash all outstanding Time Common shares for $18.50 per share. The transaction was consummated on January 31, 2018. CenterPoint Energy elected to make a reference share offer adjustment and distribute additional interest, if any, in accordance with the terms of its ZENS rather than electing to increase the early exchange ratio to 100%. CenterPoint Energy’s distribution of additional interest in connection with the reference share offer was proportionate to the percentage of eligible shares that were validly tendered by Time stockholders in Meredith’s tender offer. CenterPoint Energy received $18.50 for each share of Time Common held, resulting in cash proceeds of approximately $16 million. In accordance with the terms of the ZENS, CenterPoint Energy distributed additional interest of approximately $16 million to ZENS holders on March 6, 2018, which reduced the contingent principal amount.

As a result, CenterPoint Energy recorded the following during the nine months ended September 30, 2018:



	Meredith/Time			AT&T/TW
	(in millions)
Cash payment to ZENS note holders	$	16		$	382
Indexed debt – reduction	(4		)	(95		)
Indexed debt securities derivative – reduction	(1		)	(45		)
Loss on indexed debt securities	$	11		$	242

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



	September 30, 2018	December 31, 2017
	(in shares)
AT&T Common	0.7185	—
Charter Common	0.061382	0.061382
Time Common	—	0.0625
TW Common	—	0.5

As of September 30, 2018, the contingent principal amount of the ZENS was $98 million.

Short-Term Borrowings and Long-term Debt

9 Months Ended

Sep. 30, 2018

Debt Disclosure [Abstract]

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

Short-term Borrowings and Long-term Debt


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

Inventory Financing. NGD has AMAs associated with its utility distribution service in Arkansas, Louisiana, Mississippi, Oklahoma and Texas. In March 2018, NGD’s third party AMAs in Arkansas, Louisiana and Oklahoma expired, and NGD entered into new AMAs with CES effective April 1, 2018 in these states. The AMAs have varying terms, the longest of which expires in 2021. Pursuant to the provisions of the agreements, NGD sells natural gas and agrees to repurchase an equivalent amount of natural gas during the winter heating seasons at the same cost. These transactions are accounted for as an inventory financing and had an associated principal obligation of $ -0- and $39 million as of September 30, 2018 and December 31, 2017, respectively.


(b)	Long-term Debt

Debt Issuances. During the nine months ended September 30, 2018, the following debt instruments were issued:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
			(in millions)
Houston Electric	February 2018	General mortgage bonds	$	400	3.95%	2048
CERC Corp.	March 2018	Unsecured senior notes	300		3.55%	2023
CERC Corp.	March 2018	Unsecured senior notes	300		4.00%	2028

The proceeds from these issuances were used for general limited liability company and corporate purposes, as applicable, including to repay portions of outstanding commercial paper and borrowings under CenterPoint Energy’s money pool.

Merger Financings. On October 5, 2018, the following debt instruments were issued:



	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
		(in millions)
CenterPoint Energy	Unsecured senior notes	$	500	3.60%	2021
CenterPoint Energy	Unsecured senior notes	500		3.85%	2024
CenterPoint Energy	Unsecured senior notes	500		4.25%	2028

CenterPoint Energy intends to use the net proceeds from these debt issuances to fund a portion of the pending Merger and to pay related fees and expenses.

If CenterPoint Energy does not consummate the Merger on or prior to October 31, 2019, or if, on or prior to such date, the Merger Agreement is terminated, CenterPoint Energy will be required to redeem all of the outstanding notes at a redemption price equal to 101% of the principal amount of the notes plus accrued and unpaid interest, if any, to, but excluding, the date of such special mandatory redemption. The notes may also be redeemed at CenterPoint Energy’s option, in whole but not in part, at any time before October 31, 2019, at a redemption price equal to 101% of the aggregate principal amount thereof plus accrued and unpaid interest thereon to, but excluding, the date of such redemption, if CenterPoint Energy determines, in its reasonable judgment, that the Merger will not be consummated on or before close of business on October 31, 2019.

Credit Facility. In May 2018, CenterPoint Energy entered into an amendment to its revolving credit facility to increase the aggregate commitments from $1.7 billion to $3.3 billion effective the earlier of (i) the termination of all commitments by certain lenders to provide the Bridge Facility and (ii) the payment in full of all obligations (other than contingent obligations) under the Bridge Facility and termination of all commitments to advance additional credit thereunder, and in each case, so long as the Merger Agreement has not been terminated pursuant to the terms thereof without consummation of the Merger. This increase to CenterPoint Energy’s revolving credit facility will automatically expire on the earlier of the (a) termination date of the revolving credit facility and (b) if the Merger Agreement is terminated without consummation of the Merger, the date that is 90 days after such termination. In addition, the amendment provides for a temporary increase on the maximum ratio of debt for borrowed money to capital from 65% to 75% until the earlier of (i) June 30, 2019 and (ii) the termination of all commitments in respect of the Bridge Facility without any borrowing thereunder. On October 5, 2018, CenterPoint Energy terminated all remaining commitments by lenders to provide the Bridge Facility. As a result, the aggregate commitments under the revolving credit facility automatically increased from $1.7 billion to $3.3 billion and the maximum ratio of debt for borrowed money to capital reverted to 65%.

The Registrants had the following revolving credit facilities and utilization of such facilities:



				September 30, 2018								December 31, 2017
	Size of Facility			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	$	1,700	(1)	$	—	$	6	$	104	2.42	%	$	—	$	6	$	855	1.88	%
Houston Electric	300			—		4		—		—		—		4		—		—
CERC Corp.	900			—		1		98		2.43	%	—		1		898		1.72	%
Total	$	2,900		$	—	$	11	$	202			$	—	$	11	$	1,753


(1)	Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility increased to $3.3 billion on October 5, 2018 as a result of the satisfaction of certain conditions described above.



Execution Date	Company	Size of Facility			Draw Rate of LIBOR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of September 30, 2018 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,700	(3)	1.250%	75%	(4) (5)	47.5%	March 3, 2022
March 3, 2016	Houston Electric	300			1.125%	65%	(5)	50.7%	March 3, 2022
March 3, 2016	CERC Corp.	900			1.125%	65%		48.6%	March 3, 2022


(1)	Based on current credit ratings.


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


(3)	Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility increased to $3.3 billion on October 5, 2018 as a result of the satisfaction of certain conditions described above.


(4)	On October 5, 2018, CenterPoint Energy’s financial covenant limit returned to 65% due to the termination of all commitments in respect of the Bridge Facility without any borrowing thereunder.

(5)

For CenterPoint Energy (whenever its financial covenant limit is 65%) 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.

The Registrants were in compliance with all financial debt covenants as of September 30, 2018.

Other. As of both September 30, 2018 and December 31, 2017, Houston Electric had issued $118 million of general mortgage bonds as collateral for long-term debt of CenterPoint Energy. These bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.

Income Taxes

9 Months Ended

Sep. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes [Text Block]

Income Taxes

The Registrants reported the following effective tax rates:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
CenterPoint Energy (1)	24	%	37	%	26	%	36	%
Houston Electric (2)	20	%	35	%	21	%	36	%
CERC - Continuing operations (3) (4)	5	%	20	%	29	%	38	%
CERC - Discontinued operations (5)	23	%	38	%	24	%	38	%

(1)

CenterPoint Energy’s lower effective tax rate for the three and nine months ended September 30, 2018 compared to the same periods for 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 5% and 4%, respectively, for the three and nine months ended September 30, 2018 due to the amortization of EDIT. These decreases were partially offset by an increase to the effective tax rate of 5% for the three-month period ended September 30, 2018 as a result of the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. The effective tax rate increased by 7% for the nine-month period ended September 30, 2018 due to state law changes and the state valuation allowance. See Note 9 for further discussion on the Internal Spin.


(2)	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2018 compared to the same periods for 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate was further reduced by 2% for both periods due to the amortization of EDIT.

(3)

CERC’s lower effective tax rate on the loss from continuing operations for the three months ended September 30, 2018 compared to the same period in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 18% due to state taxes as a result of the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. These decreases were partially offset by an increase to the effective tax rate of 15% due to the amortization of EDIT. See Note 9 for further discussion on the Internal Spin.

(4)

CERC’s lower effective tax rate on income from continuing operations for the nine months ended September 30, 2018 compared to the same period in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 20% due to the amortization of EDIT. These decreases were partially offset by an increase to the effective tax rate of 22% as a result of an increase in state tax rates and the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. See Note 9 for further discussion on the Internal Spin.

(5)

CERC’s lower effective tax rate on income from discontinued operations for the three and nine months ended September 30, 2018 compared to the same periods in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. See Note 9 for further discussion on the Internal Spin and the associated discontinued operations presentation.

The Registrants reported no uncertain tax liability as of September 30, 2018 and expect no significant changes to the uncertain tax liability over the next twelve months. Tax years through 2016 have been audited and settled with the IRS, however, during the three months ended September 30, 2018, CenterPoint Energy filed an amended 2014 tax return to claim additional tax credits that is currently under review by the IRS. For the 2017 and 2018 tax years, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

Commitments and Contingencies

9 Months Ended

Sep. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies [Text Block]

Commitments and Contingencies


(a)	Natural Gas Supply Commitments (CenterPoint Energy and CERC)

Natural gas supply commitments include natural gas contracts related to CenterPoint Energy’s and CERC’s Natural Gas Distribution and Energy Services business segments, which have various quantity requirements and durations, that are not classified as non-trading derivative assets and liabilities in CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets as of September 30, 2018 and December 31, 2017 as these contracts meet an exception as “normal purchases contracts” or do not meet the definition of a derivative. Natural gas supply commitments also include natural gas transportation contracts that do not meet the definition of a derivative.

As of September 30, 2018, minimum payment obligations for natural gas supply commitments are approximately:



	(in millions)
Remaining three months of 2018	$	88
2019	325
2020	303
2021	219
2022	183
2023 and beyond	1,644


(b)	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 pending in federal court in Nevada in which CES, a subsidiary of CERC Corp., is a defendant. Plaintiffs in that case allege a conspiracy to inflate Wisconsin natural gas prices in 2000-2002. In May 2016, the district court granted CES’s motion for summary judgment, dismissing CES from the case. In August 2018, the Ninth Circuit Court of Appeals reversed that ruling, and CES requested further appellate review of that decision.

Under a master separation agreement between CenterPoint Energy and a former subsidiary, RRI, CenterPoint Energy and its subsidiaries are entitled to be indemnified by RRI and its successors for any losses, including certain attorneys’ fees and other costs, arising out of these lawsuits. Through a series of transactions, RRI became known as GenOn and a wholly-owned subsidiary of NRG. None of those transactions alters GenOn’s contractual obligations to indemnify CenterPoint Energy and its subsidiaries for certain liabilities, including their indemnification obligations regarding the gas market manipulation litigation. In June 2017, however, GenOn and various affiliates filed for protection under Chapter 11 of the U.S. Bankruptcy Code and are expected to emerge from Chapter 11 in 2018. CenterPoint Energy, CERC, and CES submitted proofs of claim in the bankruptcy proceedings to protect their indemnity rights.

In October 2018, CES, GenOn, and the plaintiffs reached an agreement to settle all claims against CES and CES’s indemnity claims against GenOn, subject to approvals by the bankruptcy court and the federal district court. If the settlement agreement is not approved and if GenOn’s bankruptcy proceedings result in it not being required to fulfill its indemnity obligations, CES could incur liability and be responsible for satisfying it. 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.

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 has reached confidential settlement agreements with some claimants. Additionally, CenterPoint Energy is cooperating with the ongoing investigation conducted by the National Transportation Safety Board. Further, CenterPoint Energy is contesting 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. CenterPoint Energy’s general and excess liability insurance policies provide coverage for third party bodily injury and property damage claims.

Environmental Matters

MGP Sites (CenterPoint Energy and CERC). CERC and its predecessors operated MGPs in the past. With respect to certain Minnesota MGP sites, CERC has completed state-ordered remediation and continues state-ordered monitoring and water treatment. As of September 30, 2018, CERC had a recorded liability of $7 million for continued monitoring and any future remediation required by regulators in Minnesota. The estimated range of possible remediation costs for the sites for which CERC believes it may have responsibility was $4 million to $30 million based on remediation continuing for 30 to 50 years. 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.

In addition to the Minnesota sites, the EPA and other regulators have investigated MGP sites that were owned or operated by CERC or may have been owned by one of its former affiliates. 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 in interest 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.

Other Environmental. From time to time, the Registrants identify the presence of environmental contaminants during operations or on property where predecessor companies have conducted operations. Other such sites involving contaminants may be identified in the future. The Registrants have and expect to continue to remediate any identified sites consistent with state and federal legal obligations. From time to time, the Registrants have received notices, and may receive notices in the future, from regulatory authorities or others regarding status as a PRP in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, the Registrants have been, or may be, named from time to time as defendants in litigation related to such sites. Although the ultimate outcome of such matters cannot be predicted at this time, the Registrants do not expect these matters, either individually or in the aggregate, to have a material adverse effect on their financial condition, results of operations or cash flows.

Other Proceedings

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

Earnings Per Share (CenterPoint Energy)

9 Months Ended

Sep. 30, 2018

Earnings Per Share [Abstract]

Earnings Per Share (CenterPoint Energy) [Text Block]

Earnings Per Share (CenterPoint Energy)

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions, except share and per share amounts)
Income available to common shareholders	$	153	$	169	$	243	$	496

Basic weighted average common shares outstanding	431,554,000		431,026,000		431,437,000		430,939,000
Plus: Incremental shares from assumed conversions:
Restricted stock	3,337,000		3,060,000		3,337,000		3,060,000
Diluted weighted average common shares	434,891,000		434,086,000		434,774,000		433,999,000

Basic earnings per common share	$	0.35	$	0.39	$	0.56	$	1.15
Diluted earnings per common share	$	0.35	$	0.39	$	0.56	$	1.14

Reportable Business Segments

9 Months Ended

Sep. 30, 2018

Segment Reporting [Abstract]

Reportable Business Segments [Text Block]

Reportable Business Segments

The Registrants’ determination of reportable business 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 business segments other than Midstream Investments, where equity in earnings is used.

As of September 30, 2018, reportable business segments by Registrant are as follows:



	Electric Transmission & Distribution	Natural Gas Distribution	Energy Services	Midstream Investments	Other Operations
CenterPoint Energy	X	X	X	X	X
Houston Electric	X
CERC		X	X	(1)	X

(1)

In the three months ended September 30, 2018, CERC completed the Internal Spin. Previously, CERC’s equity method investment in Enable was included in the Midstream Investments segment. CERC’s equity in earnings in Enable, net of basis difference amortization and income tax, has been classified as discontinued operations for all periods presented. See Note 9 for further discussion on the Internal Spin and the associated discontinued operations presentation.

Electric Transmission & Distribution consists of the electric transmission and distribution function. Natural Gas Distribution consists of intrastate natural gas sales to, and natural gas transportation and distribution for, residential, commercial, industrial and institutional customers. Energy Services consists of non-rate regulated natural gas sales and services operations. Midstream Investments consists of the equity investment in Enable (excluding the Enable Series A Preferred Units). Other Operations consists primarily of other corporate operations which support all of the business operations.

Houston Electric consists of a single reportable business segment and therefore is not included in the tabular business segment presentation below. Operating income (loss) amounts for 2017 have been recast to reflect the adoption of ASU 2017-07 (see Note 2 for further information).

Financial data for business segments is as follows:

CenterPoint Energy



	Three Months Ended September 30,
	2018									2017
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	897	(1)	$	—		$	227		$	843	(1)	$	—		$	254
Natural Gas Distribution	402			8			3			390			8			25
Energy Services	910			10			(9		)	861			10			7
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	3			—			5			4			—			11
Eliminations	—			(18		)	—			—			(18		)	—
Consolidated	$	2,212		$	—		$	226		$	2,098		$	—		$	297



	Nine Months Ended September 30,
	2018									2017
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	2,502	(1)	$	—		$	523		$	2,234	(1)	$	—		$	511
Natural Gas Distribution	2,032			26			166			1,767			24			235
Energy Services	3,008			57			(20		)	2,964			34			58
Midstream Investments (2)	—			—			—			—			^—			—
Other Operations	11			—			(5		)	11			—			24
Eliminations	—			(83		)	—			—			(58		)	—
Consolidated	$	7,553		$	—		$	664		$	6,976		$	—		$	828


(1)	CenterPoint Energy’s and Houston Electric’s Electric Transmission & Distribution revenues from major customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	213	$	221	$	543	$	540
Affiliates of Vistra Energy Corp.	79		72		192		172


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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	81	$	68	$	208	$	199

CERC



	Three Months Ended September 30,
	2018								2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	402	$	8		$	3		$	390	$	8		$	25
Energy Services	910		10			(9		)	861		10			7
Other Operations	—		—			(1		)	—		—			(1		)
Eliminations	—		(18		)	—			—		(18		)	—
Consolidated	$	1,312	$	—		$	(7	)	$	1,251	$	—		$	31



	Nine Months Ended September 30,
	2018								2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	2,032	$	26		$	166		$	1,767	$	24		$	235
Energy Services	3,008		57			(20		)	2,964		34			58
Other Operations	—		—			—			—		—			(4		)
Eliminations	—		(83		)	—			—		(58		)	—
Consolidated	$	5,040	$	—		$	146		$	4,731	$	—		$	289

CenterPoint Energy and CERC



	Total Assets
	September 30, 2018								December 31, 2017
	CenterPoint Energy				CERC				CenterPoint Energy				CERC
	(in millions)
Electric Transmission & Distribution	$	10,436			$	—			$	10,292			$	—
Natural Gas Distribution	6,557				6,557				6,608				6,608
Energy Services	1,253				1,253				1,521				1,521
Midstream Investments	2,457				—				2,472				—
Assets of discontinued operations	—				—			(1)	—				2,472			(1)
Other Operations	2,206			(2)	110				2,497			(2)	70
Eliminations	(681		)		(615		)		(654		)		(559		)
Consolidated	$	22,228			$	7,305			$	22,736			$	10,112


(1)	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 9.


(2)	Includes pension and other postemployment-related regulatory assets of $566 million and $600 million, respectively, as of September 30, 2018 and December 31, 2017.

Supplemental Disclosure of Cash Flow Information

9 Months Ended

Sep. 30, 2018

Supplemental Cash Flow Elements [Abstract]

Supplemental Disclosure of Cash Flow Information [Text Block]

Supplemental Disclosure of Cash Flow Information

The table below provides supplemental disclosure of cash flow information:



	Nine Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	301	$	173	$	85	$	306	$	176	$	86
Income taxes, net	89		122		3		14		76		4
Non-cash transactions:
Accounts payable related to capital expenditures	140		87		66		111		70		53
Capital distribution associated with the Internal Spin	—		—		1,460		—		—		—

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



	September 30, 2018				December 31, 2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Cash and cash equivalents	$	293	$	279	$	260	$	238
Restricted cash included in Prepaid expenses and other current assets	37		37		35		35
Restricted cash included in Other	1		1		1		1
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	331	$	317	$	296	$	274

CERC does not have restricted cash and therefore was not included in the table above.

Related Party Transactions (Houston Electric and CERC)

9 Months Ended

Sep. 30, 2018

Related Party Transactions (Houston Electric and CERC)

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

The table below summarizes money pool activity:



	September 30, 2018						December 31, 2017
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	(75	)	$	—		$	(60	)	$	(570	)
Weighted average interest rate	2.45		%	2.45		%	1.90		%	1.90		%


(1)	Included in Accounts and notes receivable (payable)–affiliated companies in the Condensed Consolidated Balance Sheets.

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



	Three Months Ended September 30,									Nine Months Ended September 30,
	2018					2017				2018					2017
	Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC
						(in millions)
Interest income (expense) (1)	$	1	$	(2	)	$	1	$	—	$	1	$	(4	)	$	3	$	—


(1)	Interest income is included in Other, net and interest expense is included in Interest and other finance charges on the Condensed Statements of Consolidated Income.

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

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



	Three Months Ended September 30,										Nine Months Ended September 30,
	2018					2017					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	47		$	36	$	41		$	30	$	138		$	105	$	127		$	93
Net affiliate service charges (billings)	(3		)	3		(1		)	1		(8		)	8		(6		)	6

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



	Three Months Ended September 30,								Nine Months Ended September 30,
	2018				2017				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	60	$	75	$	45	$	89	$	123	$	286	$	87	$	337
Cash contribution from parent	—		600		—		—		—		600		—		38
Capital distribution to parent associated with the Internal Spin	—		1,460		—		—		—		1,460		—		—

Equity (CenterPoint Energy)

9 Months Ended

Sep. 30, 2018

Equity [Abstract]

Equity (CenterPoint Energy) [Text Block]

Equity (CenterPoint Energy)

Dividends Declared

CenterPoint Energy declared dividends for the periods presented in the table below:



	Three Months Ended September 30,				Nine Months Ended September 30,
Equity Instrument	2018		2017		2018 (1)		2017
	(per share)
Common Stock	$	0.2775	$	0.2675	$	0.5550	$	0.8025


(1)	On December 13, 2017, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of Common Stock, payable on March 8, 2018 to shareholders of record as of the close of business on February 15, 2018.

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 intends to use the net proceeds from the Series A Preferred Stock offering to fund a portion of the pending 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 accrued during the applicable periods are presented on CenterPoint Energy’s Condensed Statements of Consolidated Income as Series A 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 intends to use the net proceeds from the offering of depositary shares, each representing a 1/20th interest in a share of Series B Preferred Stock, to fund a portion of the pending 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.

Acquisition Termination Redemption. If the pending Merger has not closed at or prior to close of business on April 21, 2019 or if an acquisition termination event occurs, CenterPoint Energy may, at its option, give notice of an acquisition termination redemption to the holders of the Series B Preferred Stock. If CenterPoint Energy provides such notice, then, on the acquisition termination redemption date, CenterPoint Energy will be required to redeem the Series B Preferred Stock, in whole but not in part, at a redemption amount per share of the Series B Preferred Stock equal to the acquisition termination redemption amount. CenterPoint Energy will pay the acquisition termination redemption amount in cash unless the acquisition termination share price is greater than the initial price, in which case CenterPoint Energy will instead pay the acquisition termination redemption amount by delivering shares of Common Stock and cash; provided, that CenterPoint Energy may elect, subject to certain limitations, to pay cash or deliver shares of Common Stock in lieu of these amounts. If CenterPoint Energy redeems shares of the Series B Preferred Stock held by the depositary, the depositary will redeem, on the same acquisition termination redemption date, the number of the depositary shares representing the shares of the Series B Preferred Stock so redeemed.

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 approximately 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 intends to use the net proceeds from the Common Stock offering to fund a portion of the pending Merger and to pay related fees and expenses.

Subsequent Events (CenterPoint Energy and CERC)	9 Months Ended
Subsequent Events (CenterPoint Energy and CERC)	Sep. 30, 2018
Subsequent Events [Abstract]
Subsequent Events (CenterPoint Energy and CERC) [Text Block]	Subsequent Events (CenterPoint Energy) CenterPoint Energy Dividend Declarations On October 23, 2018, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of Common Stock payable on December 13, 2018 to shareholders of record as of the close of business on November 15, 2018. On October 23, 2018, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $11.6667 per share of the newly issued Series B Preferred Stock ($0.5833 per depository share) payable on December 1, 2018 to shareholders of record as of the close of business on November 15, 2018. For more information about the Series B Preferred Stock, see Note 19. Enable Distributions Declarations On November 6, 2018, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common units for the quarter ended September 30, 2018. Accordingly, CNP Midstream expects to receive a cash distribution of approximately $74 million from Enable in the fourth quarter of 2018 to be made with respect to CNP Midstream’s investment in common units of Enable. On November 6, 2018, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended September 30, 2018. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the fourth quarter of 2018 to be made with respect to CenterPoint Energy’s investment in Enable Series A Preferred Units. Merger Financing Transactions On October 1, 2018, CenterPoint Energy completed concurrent equity offerings of depositary shares, each representing a 1/20th interest in a share of Series B Preferred Stock, and Common Stock. For more information about the concurrent equity offerings, see Note 19. On October 5, 2018, CenterPoint Energy issued $1.5 billion aggregate principal amount of senior notes. For more information about the senior notes offering, see Note 12.

New Accounting Pronouncements (Tables)

9 Months Ended

Sep. 30, 2018

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

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

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



Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2014-09- Revenue from Contracts with Customers (Topic 606) and related amendments	This standard provides a comprehensive new revenue recognition model that requires revenue to be recognized in a manner that depicts the transfer of goods or services to a customer at an amount that reflects the consideration expected to be received in exchange for those goods or services. Transition method: modified retrospective	January 1, 2018	Note 4 addresses the disclosure requirements. Adoption of the standard did not result in significant changes to revenue recognition. A substantial amount of the Registrants’ revenues are tariff and/or derivative based, which were not significantly impacted by these ASUs.
ASU 2017-05- Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets	This standard clarifies when and how to apply ASC 610-20, which was issued as part of ASU 2014-09. It amends or supersedes the guidance in ASC 350 and ASC 360 on determining a gain or loss recognized upon the derecognition of nonfinancial assets. Transition method: modified retrospective	January 1, 2018	ASU 2017-05 eliminates industry specific guidance, including ASC 360-20 Property, Plant, and Equipment - Real Estate Sales, for the recognition of gains or losses upon the sale of in-substance real estate. CenterPoint Energy and CERC elected to apply the practical expedient upon adoption to only evaluate transactions that were not determined to be complete as of the date of adoption. Subsequent to adoption, gains or losses on sales or dilution events in CenterPoint Energy’s investment in Enable may result in gains or losses recognized in earnings. See Note 9 for further discussion.
ASU 2016-01-Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities ASU 2018-03-Technical Corrections and Improvements to Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	This standard requires equity investments that do not result in consolidation and are not accounted for under the equity method to be measured at fair value and to recognize any changes in fair value in net income unless the investments qualify for the new practicability exception. It does not change the guidance for classifying and measuring investments in debt securities and loans. It also changes certain disclosure requirements and other aspects related to recognition and measurement of financial assets and financial liabilities. Transition method: cumulative-effect adjustment to beginning retained earnings, and two features prospective	January 1, 2018	The adoption of this standard did not have an impact on the Registrants’ financial position, results of operations or cash flows. The Registrants elected the practicability exception for investments without a readily determinable fair value to be measured at cost. This includes the Enable Series A Preferred Units owned by CenterPoint Energy, which were previously accounted for under the cost method. See Note 9 for further discussion.
ASU 2016-15- Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments	This standard provides clarifying guidance on the classification of certain cash receipts and payments in the statement of cash flows and eliminates the variation in practice related to such classifications. Transition method: retrospective	January 1, 2018	The adoption did not have a material impact on the Registrants’ financial position, results of operations or disclosures. However, CenterPoint Energy’s and Houston Electric’s Condensed Statements of Consolidated Cash Flows reflect an increase in investing activities and a corresponding decrease in operating activities of $1 million and $3 million for the nine months ended September 30, 2018 and 2017, respectively, due to the requirement that cash proceeds from COLI policies be classified as cash inflows from investing activity.



Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2016-18- Statement of Cash Flows (Topic 230): Restricted Cash	This standard requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, restricted cash and restricted cash equivalents. As a result, the statement of cash flows will no longer present transfers between cash and cash equivalents and restricted cash and restricted cash equivalents. When cash, cash equivalents, restricted cash and restricted cash equivalents are presented in more than one line item on the balance sheet, the new guidance requires a reconciliation of the totals in the statement of cash flows to the related captions in the balance sheet. Transition method: retrospective	January 1, 2018	The adoption of this standard did not have an impact on the Registrants’ financial position, results of operations or disclosures. However, CenterPoint Energy’s and Houston Electric’s Condensed Statements of Consolidated Cash Flows are reconciled to cash, cash equivalents and restricted cash, resulting in a decrease in investing activities of $2 million and an increase in investing activities of $8 million for the nine months ended September 30, 2018 and 2017, respectively. See Note 17 for further discussion.
ASU 2017-01- Business Combinations (Topic 805): Clarifying the Definition of a Business	This standard revises the definition of a business. If substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets, then under ASU 2017-01, the asset or group of assets is not a business. The guidance also requires a business to include at least one substantive process and narrows the definition of outputs to be more closely aligned with how outputs are described in ASC 606. Transition method: prospective	January 1, 2018	The adoption of this revised definition will reduce the number of transactions that are accounted for as a business combination, and therefore may have a potential impact on the Registrants’ accounting for future acquisitions.
ASU 2017-04- Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment	This standard eliminates Step 2 of the goodwill impairment test, which required a hypothetical purchase price allocation. A goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Transition method: prospective	January 1, 2018	The adoption of this standard will have an impact on CenterPoint Energy’s and CERC’s future calculation of goodwill impairments if an impairment is identified.
ASU 2017-07- Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost	This standard requires an employer to report the service cost component of the net periodic pension cost and postretirement benefit cost in the same line item(s) as other employee compensation costs arising from services rendered during the period; all other components will be presented separately from the line item(s) that includes the service cost and outside of any subtotal of operating income. In addition, only the service cost component will be eligible for capitalization in assets. Transition method: retrospective for the presentation of the service cost component and other components; prospective for the capitalization of the service cost component	January 1, 2018	The adoption of this standard did not have a material impact on the Registrants’ financial position, results of operations, cash flows or disclosures; however, it resulted in the increases to operating income and corresponding decreases to other income reported in the table below. Other components previously capitalized in assets will be recorded as regulatory assets in the Registrants’ rate-regulated businesses, prospectively.
ASU 2017-09- Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting	This standard clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as a modification. Entities will apply the modification accounting guidance if the value, vesting conditions or classification of the award changes. Transition method: prospective	January 1, 2018	The adoption of this standard will have an impact on CenterPoint Energy’s accounting for future changes to share-based payment awards.
ASU 2017-12- Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities	This standard expands an entity’s ability to hedge and account for risk components, reduces the complexity of applying certain aspects of hedge accounting and updates the presentation and disclosure requirements. The guidance eliminates the requirement to separately measure and report hedge ineffectiveness. Transition method: cumulative-effect adjustment for elimination of the separate measurement of ineffectiveness; prospective for presentation and disclosure	July 1, 2018 Applicable January 1, 2018	The adoption of this standard did not have a material impact on the Registrants’ financial position, results of operations or cash flows. As a result of the adoption, the Registrants will no longer recognize ineffectiveness for derivatives designated as cash flow hedges; all changes in fair value will flow through other comprehensive income. As the Registrants did not have existing cash flow hedges as of the initial application date and the adoption date, no cumulative effective adjustment was recorded. Note 7 reflects disclosures modified upon adoption.
ASU 2018-13- Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement	This standard eliminates, modifies and adds certain disclosure requirements for fair value measurements. Transition method: prospective for additions and one modification and retrospective for all other amendments	Adoption of eliminations and modifications as of September 30, 2018; Additions will be adopted January 1, 2020	The adoption of this standard did not impact the Registrants’ financial position, results of operations or cash flows. Note 8 reflects the disclosures modified upon adoption.

The table below reflects the impact of adoption of ASU 2017-07:



	Three Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	9	$	3	$	—	$	18	$	7	$	5
Decrease to other income	9		3		—		18		7		5
	Nine Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	38	$	18	$	8	$	52	$	22	$	16
Decrease to other income	38		18		8		52		22		16



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2016-02- Leases (Topic 842) and related amendments ASU 2018-01- Leases (Topic 842) Land Easement Practical Expedient for Transition to Topic 842 ASU 2018-10 - Codification Improvements to Topic 842, Leases ASU 2018-11- Leases (Topic 842)-Targeted Improvements	ASU 2016-02 provides a comprehensive new lease model that requires lessees to recognize assets and liabilities for most leases and would change certain aspects of lessor accounting. Transition method: modified retrospective ASU 2018-01 allows entities to elect not to assess whether existing land easements that were not previously accounted for in accordance with ASC 840 Leases under ASC 842 Leases when transitioning to the new leasing standard. ASU 2018-10 makes sixteen narrow-scope amendments to ASC 842 Leases. ASU 2018-11 allows entities the transition option to not apply the new lease standards in the comparative financial statements presented in the year of adoption. It also gives lessors the practical expedient to not separate non-lease and lease components when certain criteria are met.	January 1, 2019 Early adoption is permitted	The Registrants will elect the practical expedient on existing easements provided by ASU 2018-01, and the transition option to not apply the new lease standards in the comparative financial statements presented in the year of adoption provided by ASU 2018-11. The Registrants are evaluating other available transitional practical expedients. The Registrants are in the process of reviewing contracts to identify leases as defined in ASU 2016-02 and expect to recognize on the statements of financial position right-of-use assets and lease liabilities for the majority of their respective leases that are currently classified as operating leases. The Registrants are continuing to assess the impact that adoption of these standards will have on their financial position, results of operations, cash flows and disclosures.
ASU 2016-13- Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	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 starting January 1, 2019	The Registrants are currently assessing the impact that this standard will have on their financial position, results of operations, cash flows and disclosures.
ASU 2018-02-Income Statement-Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income	This standard allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA and requires entities to provide certain disclosures regarding stranded tax effects. Transition method: either in the period of adoption or retrospective	January 1, 2019 Early adoption is permitted	The adoption of this standard will allow the Registrants to reclass stranded deferred tax adjustments primarily related to benefit plans from other comprehensive income to retained earnings. The Registrants are currently assessing the impact that adoption of this standard will have on their financial position and disclosures.



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
ASU 2018-14-Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans	This standard eliminates, modifies and adds certain disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Transition method: retrospective	January 1, 2021 Early adoption is permitted	The adoption of this standard will impact the Registrants’ annual disclosures and is not expected to have an impact on their financial position, results of operations, and cash flows. The Registrants are currently assessing the standard’s impact on the Stock-Based Incentive Compensation Plans and Employee Benefit Plans footnote.
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 allow the Registrants to capitalize certain implementation costs incurred in cloud computing arrangements that are accounted for as service contracts. The Registrants are currently assessing the impact that adoption of this standard will have on their financial position, results of operations, cash flows and disclosures.

Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2018

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue [Table Text Block]

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

CenterPoint Energy



	Three Months Ended September 30,
	2018														2017
	Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total
	(in millions)
Revenue from contracts	$	904		$	398		$	82		$	1	$	1,385		$	852		$	396		$	97		$	2	$	1,347
Derivatives income	—			—			838			—		838			—			—			774			—		774
Other (3)	(7		)	12			—			2		7			(9		)	2			—			2		(5		)
Eliminations	—			(8		)	(10		)	—		(18		)	—			(8		)	(10		)	—		(18		)
Total revenues	$	897		$	402		$	910		$	3	$	2,212		$	843		$	390		$	861		$	4	$	2,098

	Nine Months Ended September 30,
	2018														2017
	Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Electric Transmission & Distribution (1)			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total
	(in millions)
Revenue from contracts	$	2,525		$	2,093		$	338		$	4	$	4,960		$	2,254		$	1,784		$	355		$	4	$	4,397
Derivatives income	(4		)	—			2,727			—		2,723			1			—			2,643			—		2,644
Other (3)	(19		)	(35		)	—			7		(47		)	(21		)	7			—			7		(7		)
Eliminations	—			(26		)	(57		)	—		(83		)	—			(24		)	(34		)	—		(58		)
Total revenues	$	2,502		$	2,032		$	3,008		$	11	$	7,553		$	2,234		$	1,767		$	2,964		$	11	$	6,976

Houston Electric



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Revenue from contracts	$	904		$	852		$	2,525		$	2,254
Other (3)	(7		)	(9		)	(19		)	(21		)
	$	897		$	843		$	2,506		$	2,233

CERC



	Three Months Ended September 30,
	2018									2017
	Natural Gas Distribution (1)			Energy Services (2)			Total			Natural Gas Distribution (1)			Energy Services (2)			Total
	(in millions)
Revenue from contracts	$	398		$	82		$	480		$	396		$	97		$	493
Derivatives income	—			838			838			—			774			774
Other (3)	12			—			12			2			—			2
Eliminations	(8		)	(10		)	(18		)	(8		)	(10		)	(18		)
Total revenues	$	402		$	910		$	1,312		$	390		$	861		$	1,251

	Nine Months Ended September 30,
	2018									2017
	Natural Gas Distribution (1)			Energy Services (2)			Total			Natural Gas Distribution (1)			Energy Services (2)			Total
	(in millions)
Revenue from contracts	$	2,093		$	338		$	2,431		$	1,784		$	355		$	2,139
Derivatives income	—			2,727			2,727			—			2,643			2,643
Other (3)	(35		)	—			(35		)	7			—			7
Eliminations	(26		)	(57		)	(83		)	(24		)	(34		)	(58		)
Total revenues	$	2,032		$	3,008		$	5,040		$	1,767		$	2,964		$	4,731


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


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

(3)

Employee Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2018

Retirement Benefits [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

The table below reflects the expected contributions to be made to the pension plans and postretirement benefit plan during 2018:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2018	$	67	$	—	$	—
Expected contribution to postretirement benefit plan in 2018	16		10		5

The table below reflects the contributions made to the pension plans and postretirement benefit plan during 2018:



	Three Months Ended September 30, 2018						Nine Months Ended September 30, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	3	$	—	$	—	$	67	$	—	$	—
Postretirement benefit plan	4		3		1		11		7		3

Pension Benefits (CenterPoint Energy)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Service cost (1)	$	10		$	9		$	28		$	27
Interest cost (2)	20			22			59			66
Expected return on plan assets (2)	(27		)	(24		)	(80		)	(72		)
Amortization of prior service cost (2)	3			2			7			7
Amortization of net loss (2)	10			14			32			43
Net periodic cost	$	16		$	23		$	46		$	71

Postretirement Benefits



	Three Months Ended September 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	—		$	—		$	1		$	—		$	—		$	1
Interest cost (2)	3			2			1			4			3			1
Expected return on plan assets (2)	(1		)	(1		)	—			(1		)	(1		)	(1		)
Amortization of prior service credit (2)	(1		)	(1		)	—			(1		)	(2		)	—
Net periodic cost	$	1		$	—		$	2		$	2		$	—		$	1

	Nine Months Ended September 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	1		$	1		$	—		$	1
Interest cost (2)	10			6			3			12			7			3
Expected return on plan assets (2)	(4		)	(3		)	(1		)	(4		)	(3		)	(1		)
Amortization of prior service cost (credit) (2)	(3		)	(4		)	1			(3		)	(4		)	1
Net periodic cost (credit)	$	4		$	(1	)	$	4		$	6		$	—		$	4


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


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

Schedule of Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]

Changes in accumulated other comprehensive loss related to defined benefit and postretirement plans are as follows:

CenterPoint Energy



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	(in millions)
Beginning Balance	$	(63	)	$	(70	)	$	(66	)	$	(72	)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	—			—			1			1
Actuarial losses (1)	2			2			5			5
Tax expense	(1		)	(2		)	(2		)	(4		)
Net current period other comprehensive income	1			—			4			2
Ending Balance	$	(62	)	$	(70	)	$	(62	)	$	(70	)


(1)	These accumulated other comprehensive components are included in the computation of net periodic cost.

Regulatory Accounting (Tables)

9 Months Ended

Sep. 30, 2018

Regulatory Assets and Liabilities, Other Disclosures [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

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



	September 30, 2018									December 31, 2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	60		$	—		$	60		$	130		$	—		$	130
Non-current regulatory assets:
Securitized regulatory assets	1,146			1,146			—			1,590			1,590			—
Unrecognized equity return (2)	(225		)	(225		)	—			(287		)	(287		)	—
Unamortized loss on reacquired debt	70			70			—			75			75			—
Pension and postretirement-related regulatory asset (3)	609			32			15			646			31			20
Hurricane Harvey restoration costs (4)	67			61			6			64			58			6
Regulatory assets related to TCJA (5)	48			34			14			48			33			15
Other long-term regulatory assets (6)	219			84			135			211			70			140
Total non-current regulatory assets	1,934			1,202			170			2,347			1,570			181
Total regulatory assets	1,994			1,202			230			2,477			1,570			311
Regulatory Liabilities:
Current regulatory liabilities (7)	47			22			25			24			22			2
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (5)	1,362			858			504			1,354			862			492
Estimated removal costs	887			275			612			878			285			593
Other long-term regulatory liabilities	257			132			125			232			116			116
Total non-current regulatory liabilities	2,506			1,265			1,241			2,464			1,263			1,201
Total regulatory liabilities	2,553			1,287			1,266			2,488			1,285			1,203
Total regulatory assets and liabilities, net	$	(559	)	$	(85	)	$	(1,036	)	$	(11	)	$	285		$	(892	)


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

(2)


(3)	Includes a portion of NGD’s actuarially determined pension and other postemployment expense in excess of the amount being recovered through rates that is being deferred for rate making purposes, of which $4 million and $7 million as of September 30, 2018 and December 31, 2017, respectively, were not earning a return.


(4)	The Registrants are not earning a return on Hurricane Harvey restoration costs.


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


(6)	Other long-term regulatory assets that are not earning a return were not material as of September 30, 2018 and December 31, 2017.


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

Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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

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



				Three Months Ended September 30,				Nine Months Ended September 30,
Jurisdiction	Winter Season	Bilateral Cap		2018		2017		2018			2017
		(in millions)
Certain NGD jurisdictions	2018 – 2019	$	9	$	—	$	—	$	—		$	—
Certain NGD jurisdictions	2017 – 2018	8		—		—		—			—
Total CERC (1)				—		—		—			—
Electric operations’ service territory	2018 – 2019	8		—		—		—			—
Electric operations’ service territory	2017 – 2018	9		—		—		(4		)	—
Electric operations’ service territory	2016 – 2017	9		—		—		—			1
Total CenterPoint Energy (1)				$	—	$	—	$	(4	)	$	1


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

Fair Value of Derivative Instruments [Table Text Block]

Fair Value of Derivative Instruments and Hedged Items



		September 30, 2018				December 31, 2017
	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
Derivatives designated as cash flow hedges:		(in millions)
Interest rate derivatives	Current Assets: Non-trading derivative assets	$	3	$	—	$	—	$	—
Total Houston Electric		3		—		—		—
Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	—		2		13		1
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	76		3		114		4
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	38		—		44		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	31		72		38		78
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	16		33		9		24
Total CERC		161		110		218		107
Indexed debt securities derivative	Current Liabilities	—		685		—		668
Total CenterPoint Energy		$	164	$	795	$	218	$	775


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,865 Bcf or a net 310 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of September 30, 2018 and December 31, 2017, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)


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

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



		September 30, 2018				December 31, 2017
	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
Hedged items in fair value hedge relationship:		(in millions)
Natural gas inventory	Current Assets: Natural gas inventory	$	39	$	1	$	80	$	14
Total CenterPoint Energy and CERC		$	39	$	1	$	80	$	14

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

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



	September 30, 2018									December 31, 2017
	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	$	107		$	(34	)	$	73		$	165		$	(55	)	$	110
Other Assets: Non-trading derivative assets	54			(16		)	38			53			(9		)	44
Current Liabilities: Non-trading derivative liabilities	(77		)	44			(33		)	(83		)	63			(20		)
Other Liabilities: Non-trading derivative liabilities	(33		)	27			(6		)	(24		)	20			(4		)
Total	$	51		$	21		$	72		$	111		$	19		$	130


(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 Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

Income Statement Impact of Derivative Activity [Table Text Block]

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



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (2)
	Non-utility natural gas expense						Non-utility natural gas expense
	(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	864		$	832		$	2,927		$	2,843

Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	1			4			(13		)	(10		)
Derivatives designated as hedging instruments	(1		)	(4		)	13			10
Amounts excluded from effectiveness testing recognized in earnings immediately (1)	6			(9		)	(73		)	(93		)

(1)


(2)	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 Registrants for both the three and nine months ended September 30, 2018 and 2017, respectively.



		Three Months Ended September 30,						Nine Months Ended September 30,
	Income Statement Location	2018			2017			2018			2017
Effects of derivatives not designated as hedging instruments on the income statement:		(in millions)
Commodity contracts	Gains (Losses) in Non-utility revenues	$	2		$	30		$	70		$	162
Total CERC		2			30			70			162
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(44		)	(36		)	(316		)	(59		)
Interest rate derivatives	Gains (Losses) in Interest and other finance charges	—			—			—			—
Total CenterPoint Energy		$	(42	)	$	(6	)	$	(246	)	$	103

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

Effect of Cash Flow Hedge Accounting on Accumulated Other Comprehensive Income



	Amount of Gain (Loss) Recognized in Other Comprehensive Income, Net of Tax on Derivative
	Three Months Ended September 30,					Nine Months Ended September 30,
	2018		2017			2018			2017
	(in millions)
Effects of cash flow hedging
Interest rate derivatives (1)	$	3	$	—		$	7		$	(1	)
Total Houston Electric	3		—			7			(1		)
Interest rate derivatives (1)	—		(1		)	—			(1		)
Total CERC	—		(1		)	—			(1		)
Interest rate derivatives (1)	—		(1		)	(1		)	(1		)
Total CenterPoint Energy	$	3	$	(2	)	$	6		$	(3	)

(1)

Disclosure of Credit Derivatives [Table Text Block]

CenterPoint Energy and CERC



	September 30, 2018		December 31, 2017
	(in millions)
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position	$	2	$	2
Fair value of collateral already posted	—		—
Additional collateral required to be posted if credit risk contingent features triggered	1		2

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

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

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2018

Fair Value Disclosures [Abstract]

CenterPoint Energy



	September 30, 2018											December 31, 2017
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	630	$	—	$	—	$	—		$	630	$	963	$	—	$	—	$	—		$	963
Investments, including money market funds (2)	70		—		—		—			70		68		—		—		—			68
Interest rate derivatives	3		—		—		—			3		—		—		—		—			—
Natural gas derivatives (3)	—		134		27		(50		)	111		—		161		57		(64		)	154
Hedged portion of natural gas inventory	1		—		—		—			1		14		—		—		—			14
Total assets	$	704	$	134	$	27	$	(50	)	$	815	$	1,045	$	161	$	57	$	(64	)	$	1,199
Liabilities
Indexed debt securities derivative	$	—	$	685	$	—	$	—		$	685	$	—	$	—	$	668	$	—		$	668
Natural gas derivatives (3)	—		105		5		(71		)	39		—		96		11		(83		)	24
Total liabilities	$	—	$	790	$	5	$	(71	)	$	724	$	—	$	96	$	679	$	(83	)	$	692

Houston Electric



	September 30, 2018										December 31, 2017
	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)	$	52	$	—	$	—	$	—	$	52	$	51	$	—	$	—	$	—	$	51
Interest rate derivatives	3		—		—		—		3		—		—		—		—		—
Total assets	$	55	$	—	$	—	$	—	$	55	$	51	$	—	$	—	$	—	$	51

CERC



	September 30, 2018											December 31, 2017
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)
Corporate equities	$	3	$	—	$	—	$	—		$	3	$	3	$	—	$	—	$	—		$	3
Investments, including money market funds (2)	10		—		—		—			10		11		—		—		—			11
Natural gas derivatives (3)	—		134		27		(50		)	111		—		161		57		(64		)	154
Hedged portion of natural gas inventory	1		—		—		—			1		14		—		—		—			14
Total assets	$	14	$	134	$	27	$	(50	)	$	125	$	28	$	161	$	57	$	(64	)	$	182
Liabilities
Natural gas derivatives (3)	$	—	$	105	$	5	$	(71	)	$	39	$	—	$	96	$	11	$	(83	)	$	24
Total liabilities	$	—	$	105	$	5	$	(71	)	$	39	$	—	$	96	$	11	$	(83	)	$	24


(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 of $21 million and $19 million as of September 30, 2018 and December 31, 2017, respectively, posted with the same counterparties.


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


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

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



	Three Months Ended September 30,												Nine Months Ended September 30,
	2018						2017						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	(628	)	$	13		$	(712	)	$	28		$	(622	)	$	46		$	(704	)	$	13
Total gains (losses)	1			1			(38		)	(2		)	4			4			(38		)	21
Total settlements	(1		)	(1		)	(1		)	(1		)	(36		)	(36		)	(5		)	(5		)
Transfers into Level 3	—			—			7			7			(2		)	(2		)	9			9
Transfers out of Level 3 (1)	650			9			(6		)	(6		)	678			10			(12		)	(12		)
Ending balance (2)	$	22		$	22		$	(750	)	$	26		$	22		$	22		$	(750	)	$	26

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:
	$	11		$	11		$	(36	)	$	—		$	9		$	9		$	(42	)	$	17


(1)	As of September 30, 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 sales or purchases during either of the three or nine months ended September 30, 2018 or 2017.

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



	September 30, 2018						December 31, 2017
	CenterPoint Energy (1)		Houston Electric (1)		CERC		CenterPoint Energy (1)		Houston Electric (1)		CERC
Long-term debt, including current maturities	(in millions)
Carrying amount	$	7,758	$	4,782	$	2,257	$	8,679	$	4,753	$	2,457
Fair value	7,888		4,813		2,367		9,220		5,034		2,708


(1)	Includes Securitization Bond debt.

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Tables)

9 Months Ended

Sep. 30, 2018

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Interests Held in Enable GP (CenterPoint Energy):



	September 30, 2018
	Management Rights (1)		Incentive Distribution Rights (2)
CenterPoint Energy (3)	50	%	40	%
OGE	50	%	60	%


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

(2)


(3)	Includes interests held through CNP Midstream.

Distributions Received from Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Investment in Enable common units (1)	$	74	$	74	$	223	$	223
Total CERC (2)	74		74		223		223
Investment in Enable Series A Preferred Units (3)	9		9		27		27
Total CenterPoint Energy	$	83	$	83	$	250	$	250


(1)	Reflects cash distributions of $0.318 and $0.954 per common unit for the three and nine months ended September 30, 2018 and 2017, respectively.


(2)	On September 4, 2018, CERC completed the Internal Spin. After such date, CNP Midstream owned the Enable common units previously owned by CERC.


(3)	Reflects cash distributions of $0.625 and $1.875 per Enable Series A Preferred Unit for the three and nine months ended September 30, 2018 and 2017, respectively.

Transactions with Enable (CenterPoint Energy and CERC):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Reimbursement of transition services (1) (CenterPoint Energy)	$	1	$	—	$	4	$	3
Natural gas expenses, including transportation and storage costs (CenterPoint Energy and CERC)	23		23		89		80


(1)	Represents amounts billed under the Transition Agreements for certain support services provided to Enable. Actual transition services costs are recorded net of reimbursement.



	September 30, 2018		December 31, 2017
	(in millions)
Accounts receivable for amounts billed for transition services (CenterPoint Energy)	$	3	$	1
Accounts payable for natural gas purchases from Enable (CenterPoint Energy and CERC)	8		13

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Operating revenues	$	928	$	705	$	2,481	$	1,997
Cost of sales, excluding depreciation and amortization	516		349		1,335		936
Depreciation and amortization	100		90		292		267
Operating income	171		137		436		399
Net income attributable to Enable common units	129		104		320		301
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	70	$	56	$	173	$	163
Basis difference amortization (1)	11		12		35		36
CenterPoint Energy’s equity in earnings, net	$	81	$	68	$	208	$	199

(1)

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



	September 30, 2018			December 31, 2017
	(in millions)
Current assets	$	481		$	416
Non-current assets	11,454			11,177
Current liabilities	1,403			1,279
Non-current liabilities	2,964			2,660
Non-controlling interest	11			12
Preferred equity	362			362
Enable partners’ equity	7,195			7,280
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,883		$	3,935
CenterPoint Energy’s basis difference	(1,426		)	(1,463		)
CenterPoint Energy’s equity method investment in Enable	$	2,457		$	2,472

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



	September 30, 2018
	Limited Partner Interest (1)		Common Units	Enable Series A Preferred Units (2)
CenterPoint Energy (3)	54.0	%	233,856,623	14,520,000
OGE	25.6	%	110,982,805	—
Public unitholders	20.4	%	88,376,728	—
Total units outstanding	100.0	%	433,216,156	14,520,000


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

(2)


(3)	Includes Enable Series A Preferred Units held directly by CenterPoint Energy and common units held indirectly through CNP Midstream.

Discontinued Operations (CERC) [Table Text Block]



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Equity in earnings of unconsolidated affiliate, net	$	57	$	68	$	184	$	199
Income tax expense	13		26		44		75
Income from discontinued operations, net of tax	$	44	$	42	$	140	$	124

Goodwill and Intangible Assets Disclosure [Abstract]

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

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=65878427&loc=SL51721533-107759

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721665-107760

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=64827811&loc=d3e1474-107760

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=64827811&loc=d3e1361-107760

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721683-107760

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=84176398&loc=SL51724579-110230

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5C
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721675-107760

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721663-107760

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=84176398&loc=d3e2941-110230

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5B
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721673-107760

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721659-107760

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5A
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721671-107760

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5D
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721677-107760

+ Details

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

9 Months Ended

Sep. 30, 2018

Schedule of Goodwill [Table Text Block]

CenterPoint Energy’s and CERC’s goodwill by reportable business segment as of both September 30, 2018 and December 31, 2017 is as follows:



	(in millions)
Natural Gas Distribution	$	746
Energy Services (1)	110
Other Operations	11
Total	$	867

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

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

The tables below present information on CenterPoint Energy’s and CERC’s other intangible assets recorded in Other non-current assets on the Condensed Consolidated Balance Sheets.



		September 30, 2018							December 31, 2017
	Useful Lives	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in years)	(in millions)
Customer relationships	15	$	86	$	(26	)	$	60	$	86	$	(21	)	$	65
Covenants not to compete	4	4		(2		)	2		4		(2		)	2
Other	Various	15		(10		)	5		15		(8		)	7
Total		$	105	$	(38	)	$	67	$	105	$	(31	)	$	74

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Amortization expense of intangible assets	$	2	$	2	$	7	$	5

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

9 Months Ended

Sep. 30, 2018

Investments, Debt and Equity Securities [Abstract]

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

As a result, CenterPoint Energy recorded the following during the nine months ended September 30, 2018:



	Meredith/Time			AT&T/TW
	(in millions)
Cash payment to ZENS note holders	$	16		$	382
Indexed debt – reduction	(4		)	(95		)
Indexed debt securities derivative – reduction	(1		)	(45		)
Loss on indexed debt securities	$	11		$	242

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



	September 30, 2018	December 31, 2017
	(in shares)
AT&T Common	0.7185	—
Charter Common	0.061382	0.061382
Time Common	—	0.0625
TW Common	—	0.5



	Shares Held
	September 30, 2018	December 31, 2017
AT&T Common	10,212,945	—
Charter Common	872,503	872,503
Time Common	—	888,392
TW Common	—	7,107,130

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

9 Months Ended

Sep. 30, 2018

Debt Disclosure [Abstract]

Schedule of Debt [Table Text Block]

Debt Issuances. During the nine months ended September 30, 2018, the following debt instruments were issued:



	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
			(in millions)
Houston Electric	February 2018	General mortgage bonds	$	400	3.95%	2048
CERC Corp.	March 2018	Unsecured senior notes	300		3.55%	2023
CERC Corp.	March 2018	Unsecured senior notes	300		4.00%	2028

Merger Financings. On October 5, 2018, the following debt instruments were issued:



	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date
		(in millions)
CenterPoint Energy	Unsecured senior notes	$	500	3.60%	2021
CenterPoint Energy	Unsecured senior notes	500		3.85%	2024
CenterPoint Energy	Unsecured senior notes	500		4.25%	2028

CenterPoint Energy intends to use the net proceeds from these debt issuances to fund a portion of the pending Merger and to pay related fees and expenses.

Schedule of Line of Credit Facilities [Table Text Block]

The Registrants had the following revolving credit facilities and utilization of such facilities:



				September 30, 2018								December 31, 2017
	Size of Facility			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	$	1,700	(1)	$	—	$	6	$	104	2.42	%	$	—	$	6	$	855	1.88	%
Houston Electric	300			—		4		—		—		—		4		—		—
CERC Corp.	900			—		1		98		2.43	%	—		1		898		1.72	%
Total	$	2,900		$	—	$	11	$	202			$	—	$	11	$	1,753


(1)	Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility increased to $3.3 billion on October 5, 2018 as a result of the satisfaction of certain conditions described above.



Execution Date	Company	Size of Facility			Draw Rate of LIBOR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of September 30, 2018 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,700	(3)	1.250%	75%	(4) (5)	47.5%	March 3, 2022
March 3, 2016	Houston Electric	300			1.125%	65%	(5)	50.7%	March 3, 2022
March 3, 2016	CERC Corp.	900			1.125%	65%		48.6%	March 3, 2022


(1)	Based on current credit ratings.


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


(3)	Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility increased to $3.3 billion on October 5, 2018 as a result of the satisfaction of certain conditions described above.


(4)	On October 5, 2018, CenterPoint Energy’s financial covenant limit returned to 65% due to the termination of all commitments in respect of the Bridge Facility without any borrowing thereunder.

(5)

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2018

Income Tax Disclosure [Abstract]

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

The Registrants reported the following effective tax rates:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
CenterPoint Energy (1)	24	%	37	%	26	%	36	%
Houston Electric (2)	20	%	35	%	21	%	36	%
CERC - Continuing operations (3) (4)	5	%	20	%	29	%	38	%
CERC - Discontinued operations (5)	23	%	38	%	24	%	38	%

(1)


(2)	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2018 compared to the same periods for 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate was further reduced by 2% for both periods due to the amortization of EDIT.

(3)

(4)

(5)

Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment [Table Text Block]

As of September 30, 2018, minimum payment obligations for natural gas supply commitments are approximately:



	(in millions)
Remaining three months of 2018	$	88
2019	325
2020	303
2021	219
2022	183
2023 and beyond	1,644

Earnings Per Share (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2018

Earnings Per Share [Abstract]

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

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions, except share and per share amounts)
Income available to common shareholders	$	153	$	169	$	243	$	496

Basic weighted average common shares outstanding	431,554,000		431,026,000		431,437,000		430,939,000
Plus: Incremental shares from assumed conversions:
Restricted stock	3,337,000		3,060,000		3,337,000		3,060,000
Diluted weighted average common shares	434,891,000		434,086,000		434,774,000		433,999,000

Basic earnings per common share	$	0.35	$	0.39	$	0.56	$	1.15
Diluted earnings per common share	$	0.35	$	0.39	$	0.56	$	1.14

Reportable Business Segments (Tables)

9 Months Ended

Sep. 30, 2018

Segment Reporting [Abstract]

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

Financial data for business segments is as follows:

CenterPoint Energy



	Three Months Ended September 30,
	2018									2017
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	897	(1)	$	—		$	227		$	843	(1)	$	—		$	254
Natural Gas Distribution	402			8			3			390			8			25
Energy Services	910			10			(9		)	861			10			7
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	3			—			5			4			—			11
Eliminations	—			(18		)	—			—			(18		)	—
Consolidated	$	2,212		$	—		$	226		$	2,098		$	—		$	297



	Nine Months Ended September 30,
	2018									2017
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	2,502	(1)	$	—		$	523		$	2,234	(1)	$	—		$	511
Natural Gas Distribution	2,032			26			166			1,767			24			235
Energy Services	3,008			57			(20		)	2,964			34			58
Midstream Investments (2)	—			—			—			—			^—			—
Other Operations	11			—			(5		)	11			—			24
Eliminations	—			(83		)	—			—			(58		)	—
Consolidated	$	7,553		$	—		$	664		$	6,976		$	—		$	828


(1)	CenterPoint Energy’s and Houston Electric’s Electric Transmission & Distribution revenues from major customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	213	$	221	$	543	$	540
Affiliates of Vistra Energy Corp.	79		72		192		172


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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	81	$	68	$	208	$	199

CERC



	Three Months Ended September 30,
	2018								2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	402	$	8		$	3		$	390	$	8		$	25
Energy Services	910		10			(9		)	861		10			7
Other Operations	—		—			(1		)	—		—			(1		)
Eliminations	—		(18		)	—			—		(18		)	—
Consolidated	$	1,312	$	—		$	(7	)	$	1,251	$	—		$	31



	Nine Months Ended September 30,
	2018								2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)
Natural Gas Distribution	$	2,032	$	26		$	166		$	1,767	$	24		$	235
Energy Services	3,008		57			(20		)	2,964		34			58
Other Operations	—		—			—			—		—			(4		)
Eliminations	—		(83		)	—			—		(58		)	—
Consolidated	$	5,040	$	—		$	146		$	4,731	$	—		$	289

CenterPoint Energy and CERC



	Total Assets
	September 30, 2018								December 31, 2017
	CenterPoint Energy				CERC				CenterPoint Energy				CERC
	(in millions)
Electric Transmission & Distribution	$	10,436			$	—			$	10,292			$	—
Natural Gas Distribution	6,557				6,557				6,608				6,608
Energy Services	1,253				1,253				1,521				1,521
Midstream Investments	2,457				—				2,472				—
Assets of discontinued operations	—				—			(1)	—				2,472			(1)
Other Operations	2,206			(2)	110				2,497			(2)	70
Eliminations	(681		)		(615		)		(654		)		(559		)
Consolidated	$	22,228			$	7,305			$	22,736			$	10,112


(1)	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 9.


(2)	Includes pension and other postemployment-related regulatory assets of $566 million and $600 million, respectively, as of September 30, 2018 and December 31, 2017.

As of September 30, 2018, reportable business segments by Registrant are as follows:



	Electric Transmission & Distribution	Natural Gas Distribution	Energy Services	Midstream Investments	Other Operations
CenterPoint Energy	X	X	X	X	X
Houston Electric	X
CERC		X	X	(1)	X

(1)

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

CenterPoint Energy’s and Houston Electric’s Electric Transmission & Distribution revenues from major customers are as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	213	$	221	$	543	$	540
Affiliates of Vistra Energy Corp.	79		72		192		172

Midstream Investments [Table Text Block]

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	81	$	68	$	208	$	199

Supplemental Disclosure of Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2018

Supplemental Cash Flow Elements [Abstract]

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

The table below provides supplemental disclosure of cash flow information:



	Nine Months Ended September 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	301	$	173	$	85	$	306	$	176	$	86
Income taxes, net	89		122		3		14		76		4
Non-cash transactions:
Accounts payable related to capital expenditures	140		87		66		111		70		53
Capital distribution associated with the Internal Spin	—		—		1,460		—		—		—



	September 30, 2018				December 31, 2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Cash and cash equivalents	$	293	$	279	$	260	$	238
Restricted cash included in Prepaid expenses and other current assets	37		37		35		35
Restricted cash included in Other	1		1		1		1
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	331	$	317	$	296	$	274

CERC does not have restricted cash and therefore was not included in the table above.

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

9 Months Ended

Sep. 30, 2018

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

The table below summarizes money pool activity:



	September 30, 2018						December 31, 2017
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	(75	)	$	—		$	(60	)	$	(570	)
Weighted average interest rate	2.45		%	2.45		%	1.90		%	1.90		%


(1)	Included in Accounts and notes receivable (payable)–affiliated companies in the Condensed Consolidated Balance Sheets.

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



	Three Months Ended September 30,									Nine Months Ended September 30,
	2018					2017				2018					2017
	Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC
						(in millions)
Interest income (expense) (1)	$	1	$	(2	)	$	1	$	—	$	1	$	(4	)	$	3	$	—


(1)	Interest income is included in Other, net and interest expense is included in Interest and other finance charges on the Condensed Statements of Consolidated Income.

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



	Three Months Ended September 30,										Nine Months Ended September 30,
	2018					2017					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	47		$	36	$	41		$	30	$	138		$	105	$	127		$	93
Net affiliate service charges (billings)	(3		)	3		(1		)	1		(8		)	8		(6		)	6

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



	Three Months Ended September 30,								Nine Months Ended September 30,
	2018				2017				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Cash dividends paid to parent	$	60	$	75	$	45	$	89	$	123	$	286	$	87	$	337
Cash contribution from parent	—		600		—		—		—		600		—		38
Capital distribution to parent associated with the Internal Spin	—		1,460		—		—		—		1,460		—		—

Equity (CenterPoint Energy) (Tables)

9 Months Ended

Sep. 30, 2018

Equity [Abstract]

Dividends Declared [Table Text Block]

CenterPoint Energy declared dividends for the periods presented in the table below:



	Three Months Ended September 30,				Nine Months Ended September 30,
Equity Instrument	2018		2017		2018 (1)		2017
	(per share)
Common Stock	$	0.2775	$	0.2675	$	0.5550	$	0.8025


(1)	On December 13, 2017, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of Common Stock, payable on March 8, 2018 to shareholders of record as of the close of business on February 15, 2018.

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

Background and Basis of Presentation (Details)

9 Months Ended

Sep. 30, 2018

state

Enable Midstream Partners [Member]

Ownership percentage of equity method investment

54.00%

^[1],[2]

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

Preferred units held | shares

14,520,000

^[2],[3]

Number of states in which entity operates

Number of states in which entity operates

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

Management rights ownership percentage

50.00%

^[4],[5]

Incentive distribution right

40.00%

^[5],[6]

[1]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[2]	Includes Enable Series A Preferred Units held directly by CenterPoint Energy and common units held indirectly through CNP Midstream.
[3]	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both September 30, 2018 and December 31, 2017. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods. See Note 2 for further discussion.
[4]	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.
[5]	Includes interests held through CNP Midstream.
[6]	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.

New Accounting Pronouncements (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Accounting Standards Update 2016-15 [Member]
Effect of change on cash flow activities due to adoption of new ASU			$ 1	$ 3
Accounting Standards Update 2016-15 [Member] \| Houston Electric [Member]
Effect of change on cash flow activities due to adoption of new ASU			1	3
Accounting Standards Update 2016-18 [Member]
Effect of change on cash flow activities due to adoption of new ASU			(2)	8
Accounting Standards Update 2016-18 [Member] \| Houston Electric [Member]
Effect of change on cash flow activities due to adoption of new ASU			(2)	8
Accounting Standards Update 2017-07 [Member] \| Operating Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	$ 9	$ 18	38	52
Accounting Standards Update 2017-07 [Member] \| Other Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	(9)	(18)	(38)	(52)
Accounting Standards Update 2017-07 [Member] \| Houston Electric [Member] \| Operating Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	3	7	18	22
Accounting Standards Update 2017-07 [Member] \| Houston Electric [Member] \| Other Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	(3)	(7)	(18)	(22)
Accounting Standards Update 2017-07 [Member] \| CERC Corp [Member] \| Operating Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	0	5	8	16
Accounting Standards Update 2017-07 [Member] \| CERC Corp [Member] \| Other Income [Member]
Increase to operating income and corresponding (decrease) to other income from the adoption of ASU 2017-07	$ 0	$ (5)	$ (8)	$ (16)

Pending Merger with Vectren (CenterPoint Energy) (Details) $ / shares in Units, $ in Millions		9 Months Ended
	Oct. 01, 2018	Sep. 30, 2018 USD ($) $ / shares	Dec. 31, 2017 USD ($)
Amount of cash to be paid to acquire Vectren		$ 6,000
Cash to be paid per share of Vectren common stock prior to closing of the Merger \| $ / shares		$ 72.00
Short-term debt		$ 0	$ 39
Anticipated amount of short and long-term debt at the closing of the Merger		2,500
Vectren [Member]
Short-term debt		325
Long-term debt, including current maturities		2,000
Termination fee		150
CenterPoint Energy [Member]
Termination fee		$ 210
Series B Preferred Stock [Member] \| Subsequent Event [Member]
Depositary share interest in a share of Series B Preferred Stock	0.05

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

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

$ 1,385

$ 1,347

$ 4,960

$ 4,397

838

774

2,723

2,644

^[1]

(5)

(47)

(7)

Intersegment Eliminations [Member]

2,212

2,098

7,553

6,976

Electric Transmission and Distribution [Member]

(18)

(83)

(58)

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

^[2]

897

843

2,502

2,234

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

402

390

2,032

1,767

(8)

(26)

(24)

Energy Services [Member] | Intersegment Eliminations [Member]

910

861

3,008

2,964

Other Operations [Member]

(10)

(57)

(34)

Other Operations [Member] | Intersegment Eliminations [Member]

Reportable Subsegments [Member] | Intersegment Eliminations [Member]

^[3]

(8)

(26)

(24)

^[4]

(10)

(57)

(34)

Reportable Subsegments [Member] | Electric Transmission and Distribution [Member]

(18)

(83)

(58)

^[3]

904

852

2,525

2,254

^[3]

(4)

^[1],[3]

(7)

(9)

(19)

(21)

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

^[3]

897

843

2,502

2,234

^[3]

398

396

2,093

1,784

^[3]

^[1],[3]

(35)

Reportable Subsegments [Member] | Energy Services [Member]

^[3]

402

390

2,032

1,767

^[4]

338

355

^[4]

838

774

2,727

2,643

^[1],[4]

Reportable Subsegments [Member] | Other Operations [Member]

^[4]

910

861

3,008

2,964

^[4]

^[4]

^[1],[4]

^[4]

Houston Electric [Member] | Reportable Subsegments [Member] | Electric Transmission and Distribution [Member]

897

843

2,506

2,233

904

852

2,525

2,254

^[1]

(7)

(9)

(19)

(21)

897

843

2,506

2,233

480

493

2,431

2,139

838

774

2,727

2,643

^[1]

(35)

CERC Corp [Member] | Intersegment Eliminations [Member]

1,312

1,251

5,040

4,731

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

(18)

(83)

(58)

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

402

390

2,032

1,767

CERC Corp [Member] | Energy Services [Member]

(8)

(26)

(24)

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

910

861

3,008

2,964

CERC Corp [Member] | Other Operations [Member]

(10)

(57)

(34)

CERC Corp [Member] | Other Operations [Member] | Intersegment Eliminations [Member]

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

^[3]

(8)

(26)

(24)

^[4]

(10)

(57)

(34)

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

(18)

(83)

(58)

^[3]

398

396

2,093

1,784

^[3]

^[1],[3]

(35)

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

^[3]

402

390

2,032

1,767

^[4]

338

355

^[4]

838

774

2,727

2,643

^[1],[4]

Defined Benefit Plan, Change in Accumulated Comprehensive Loss [Roll Forward]

^[4]

$ 910

$ 861

$ 3,008

$ 2,964

[1]	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.
[2]	CenterPoint Energy’s and Houston Electric’s Electric Transmission & Distribution revenues from major customers are as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 (in millions)Affiliates of NRG $213 $221 $543 $540Affiliates of Vistra Energy Corp. 79 72 192 172
[3]	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.
[4]	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

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

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Beginning Balance

$ (63)

$ (70)

$ (66)

$ (72)

Amounts reclassified from accumulated other comprehensive loss:

Prior service cost (1)

^[1]

Actuarial losses (1)

^[1]

Tax expense

(1)

(2)

(4)

Net current period other comprehensive income

Ending Balance

(62)

(70)

(62)

(70)

Pension Benefits [Member]

Other Postretirement Benefits Plan [Member]

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

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

^[2]

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

^[2]

^[3]

^[3]

(27)

(24)

(80)

(72)

Amortization of net loss (2)

^[3]

^[3]

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

^[3]

^[3]

(1)

(4)

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

^[3]

(1)

(3)

(1)

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

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

^[2]

^[3]

^[3]

(1)

(3)

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

^[3]

(1)

(2)

(4)

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

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

^[2]

^[3]

^[3]

(1)

Securitized regulatory assets

^[3]

$ 0

$ 1

[1]	These accumulated other comprehensive components are included in the computation of net periodic cost.
[2]	Amounts presented in the table above are included in Operation and maintenance expense in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.
[3]	Amounts presented in the table above are included in Other, net in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of regulatory deferrals.

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

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

$ 1,146

$ 1,590

Unrecognized equity return (2)

^[1]

(225)

(287)

Unamortized loss on reacquired debt

1,934

2,347

1,994

2,477

Total regulatory liabilities

2,506

2,464

2,553

2,488

Total regulatory assets and liabilities, net

(559)

(11)

Securitized regulatory assets

1,146

1,590

Unrecognized equity return (2)

^[1]

(225)

(287)

Unamortized loss on reacquired debt

1,202

1,570

1,202

1,570

Total regulatory liabilities

1,265

1,263

1,287

1,285

Total regulatory assets and liabilities, net

(85)

285

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

$ 13

$ 30

Securitized regulatory assets

Unrecognized equity return (2)

^[1]

Unamortized loss on reacquired debt

170

181

230

311

Total regulatory liabilities

1,241

1,201

1,266

1,203

Total regulatory assets and liabilities, net

(1,036)

(892)

Hurricane Harvey [Member]

Hurricane Harvey [Member] | Houston Electric [Member]

^[2]

Hurricane Harvey [Member] | CERC Corp [Member]

^[2]

Prepaid expenses and other current assets [Member]

^[2]

Current regulatory assets (1)

^[3]

130

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

Current regulatory assets (1)

^[3]

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

Current regulatory assets (1)

^[3]

130

Other current liabilities [Member]

Current regulatory liabilities (7)

^[4]

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

Current regulatory liabilities (7)

^[4]

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

Current regulatory liabilities (7)

^[4]

Pension and Other Postretirement Plans Costs [Member]

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

^[5]

609

646

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

^[5]

Amounts related to TCJA [Member]

^[5]

^[6]

^[6]

Other Regulatory Assets (Liabilities) [Member]

^[6]

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

^[7]

219

211

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

^[7]

Amounts related to TCJA [Member]

^[7]

135

140

^[6]

1,362

1,354

^[6]

858

862

^[6]

504

492

Removal Costs [Member]

Removal Costs [Member] | Houston Electric [Member]

887

878

Removal Costs [Member] | CERC Corp [Member]

275

285

Other Regulatory Assets (Liabilities) [Member]

612

593

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

257

232

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

132

116

Natural Gas Distribution [Member] | Pension and Other Postretirement Plans Costs [Member]

125

116

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

$ 4

$ 7

[1]	The unrecognized equity return will be recognized as it is recovered in rates through 2024. During the three months ended September 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $17 million and $13 million, respectively, of the allowed equity return. During the nine months ended September 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $62 million and $30 million, respectively, of the allowed equity return. 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.
[2]	The Registrants are not earning a return on Hurricane Harvey restoration costs.
[3]	Current regulatory assets are included in Prepaid expenses and other current assets in the Registrants’ Condensed Consolidated Balance Sheets.
[4]	Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Condensed Consolidated Balance Sheets.
[5]	Includes a portion of NGD’s actuarially determined pension and other postemployment expense in excess of the amount being recovered through rates that is being deferred for rate making purposes, of which $4 million and $7 million as of September 30, 2018 and December 31, 2017, respectively, were not earning a return.
[6]	The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities.
[7]	Other long-term regulatory assets that are not earning a return were not material as of September 30, 2018 and December 31, 2017.

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

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Oct. 31, 2018

Dec. 31, 2017

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

Weather hedges term

10 years

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

^[1]

$ 0

$ (4)

$ 1

2018 to 2019 [Member] | Electric Transmission and Distribution [Member]

2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]

2017 to 2018 [Member] | Natural Gas Distribution [Member]

2017 to 2018 [Member] | Electric Transmission and Distribution [Member]

2017 to 2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]

2016 to 2017 [Member] | Electric Transmission and Distribution [Member]

(4)

2016 to 2017 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]

Houston Electric [Member] | Interest Rate Contract [Member]

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

100

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

^[1]

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]

$ 0

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

$ 200

$ 0

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

$ 0

$ 100

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

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

3 Months Ended

9 Months Ended

12 Months Ended

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Sep. 30, 2018

USD ($)

Bcf

Sep. 30, 2017

USD ($)

Dec. 31, 2017

USD ($)

Bcf

$ 164

$ 218

795

775

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

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

^[1]

864

$ 832

2,927

$ 2,843

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

(42)

(6)

(246)

103

Net deferred gain (loss) from cash flow hedges (net of tax)

(2)

(3)

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

Fair value of collateral already posted

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

Interest Rate Contract [Member]

Net deferred gain (loss) from cash flow hedges (net of tax)

^[2]

(1)

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

Energy Related Derivative [Member]

$ 1

Derivative gross volume notional amount (in Bcf) | Bcf

1,865

1,795

Net amount presented in the consolidated balance sheets

^[3]

$ 72

$ 130

Gross Amounts Offset in the Consolidated Balance Sheets

^[4]

111

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

^[3]

110

^[4]

107

165

(34)

(55)

^[3]

^[4]

(16)

(9)

^[4]

(77)

(83)

Derivative Liability

^[3]

(33)

(20)

^[4]

(33)

(24)

Derivative Liability

^[3]

(6)

$ (6)

$ (4)

Derivative gross volume notional amount (in Bcf) | Bcf

310

224

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

$ 0

685

668

Net deferred gain (loss) from cash flow hedges (net of tax)

(1)

Houston Electric [Member] | Interest Rate Contract [Member]

Net deferred gain (loss) from cash flow hedges (net of tax)

^[2]

(1)

161

218

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

110

107

864

832

2,927

2,843

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

162

Net deferred gain (loss) from cash flow hedges (net of tax)

(1)

CERC Corp [Member] | Interest Rate Contract [Member]

Net deferred gain (loss) from cash flow hedges (net of tax)

^[2]

(1)

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

^[5],[6],[7]

114

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

^[5],[6],[7]

^[5],[6],[7]

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

^[5],[6],[7]

^[5],[6],[7]

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

^[5],[6],[7]

^[5],[6],[7]

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

^[5],[6],[7]

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

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

^[5],[6],[7]

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

^[5],[6],[7]

$ 1

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

162

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

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

^[1]

(13)

(10)

Amounts excluded from effectiveness testing recognized in earnings immediately (1)

^[1],[8]

(9)

(73)

(93)

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

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

^[1]

(1)

(4)

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

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

(44)

(36)

(316)

(59)

Gains (Losses) in Interest and other finance charges [Member] | Interest Rate Contract [Member]

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

Gains (Losses) in Interest and other finance charges [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]

Gain (loss) reclassified from accumulated OCI into income

$ 1

$ (1)

$ 1

$ (1)

[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 Registrants for both the three and nine months ended September 30, 2018 and 2017, respectively.
[2]	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 the Condensed Statements of Consolidated Income. Amounts are less than $1 million for each of the three and nine months ended September 30, 2018 and 2017. Over the next twelve months, estimated amortization of accumulated other comprehensive income into related income is expected to be immaterial.
[3]	The derivative assets and liabilities on the Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.
[4]	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.
[5]	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.
[6]	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities was a $72 million asset and a $130 million asset as of September 30, 2018 and December 31, 2017, respectively, as shown on CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets (and as detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $21 million and $19 million, respectively.
[7]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,865 Bcf or a net 310 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of September 30, 2018 and December 31, 2017, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.
[8]	As a result of the adoption of ASU 2017-12 effective January 1, 2018 (see Note 2 for additional information), CenterPoint Energy and CERC exclude from their assessment of hedge effectiveness the natural gas market price difference between locations of the hedged inventory and the delivery location specified in the hedge instruments. Prior to the adoption of this accounting guidance, the timing difference between the spot price and the futures price, as well as the difference between the timing of the settlement of the futures and the valuation of the underlying physical commodity, was excluded from the assessment of effectiveness for CenterPoint Energy’s and CERC’s existing fair value hedges and will continue to be excluded from the assessment of hedge effectiveness. CenterPoint Energy and CERC elected to continue to immediately recognize amounts excluded from hedge effectiveness in their respective Condensed Statements of Consolidated Income.

Fair Value Measurements (Details)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Dec. 31, 2017

USD ($)

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

$ 724

$ 692

Assets

Total derivative assets, netting adjustment

815

1,199

^[1]

(50)

(64)

Total derivative liabilities, netting adjustment

^[1]

(71)

(83)

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

Beginning balance

(628)

$ (712)

(622)

$ (704)

Total gains (losses)

(38)

Total settlements

(1)

(36)

(5)

Transfers into Level 3

(2)

Transfers out of Level 3 (1)

^[2]

650

(6)

678

(12)

Ending balance (2)

^[3]

(750)

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:

(36)

(42)

Carrying Amount [Member]

^[4]

7,758

8,679

Fair Value [Member]

Energy Related Derivative [Member]

^[4]

7,888

9,220

Assets

Derivative fair value offsets, net

Fair Value, Inputs, Level 1 [Member]

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

Assets

Fair Value, Inputs, Level 2 [Member]

704

1,045

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

790

Assets

Fair Value, Inputs, Level 3 [Member]

134

161

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

679

Assets

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

$ 27

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

Fair value inputs (price per MMBtu)

1.28

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

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

Fair value inputs (price per MMBtu)

6.88

Fair Value, Measurements, Recurring [Member]

Assets

630

$ 630

963

^[5]

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

Assets

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

Assets

Derivative asset, netting adjustment

^[1],[6]

(50)

(64)

^[6]

111

154

Derivative liabilities, netting adjustment

^[1],[6]

(71)

(83)

Derivative liabilities

^[6]

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

Derivative liabilities, netting adjustment

^[1]

Derivative liabilities

685

668

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

Assets

630

963

^[5]

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

Assets

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

Assets

^[6]

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

^[6]

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

Assets

^[5]

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

Assets

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

Assets

^[6]

134

161

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

^[6]

105

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

685

Assets

^[5]

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

Assets

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

Assets

^[6]

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

^[6]

668

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

Assets

Total derivative assets, netting adjustment

125

182

^[1]

(50)

(64)

Total derivative liabilities, netting adjustment

^[1]

(71)

(83)

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

Beginning balance

Total gains (losses)

(2)

Total settlements

(1)

(36)

(5)

Transfers into Level 3

(2)

Transfers out of Level 3 (1)

^[2]

(6)

(12)

Ending balance (2)

^[3]

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:

$ 0

$ 17

CERC Corp [Member] | Carrying Amount [Member]

CERC Corp [Member] | Fair Value [Member]

2,257

2,457

CERC Corp [Member] | Fair Value, Inputs, Level 1 [Member]

2,367

2,708

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

Assets

CERC Corp [Member] | Fair Value, Inputs, Level 2 [Member]

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

105

Assets

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

134

161

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

Assets

CERC Corp [Member] | Fair Value, Measurements, Recurring [Member]

Assets

^[5]

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

Assets

Derivative asset, netting adjustment

^[1],[6]

(50)

(64)

^[6]

111

154

Derivative liabilities, netting adjustment

^[1],[6]

(71)

(83)

Derivative liabilities

^[6]

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

Assets

^[5]

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

Assets

^[6]

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

^[6]

Assets

^[5]

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

Assets

^[6]

134

161

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

^[6]

105

Assets

^[5]

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

Assets

^[6]

^[6]

Assets

Total derivative assets, netting adjustment

Houston Electric [Member] | Carrying Amount [Member]

Houston Electric [Member] | Fair Value [Member]

^[4]

4,782

4,753

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

^[4]

4,813

5,034

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]

Assets

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]

Assets

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]

Assets

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

$ 0

[1]	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy and CERC to settle positive and negative positions and also include cash collateral of $21 million and $19 million as of September 30, 2018 and December 31, 2017, respectively, posted with the same counterparties.
[2]	As of September 30, 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.
[3]	CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during either of the three or nine months ended September 30, 2018 or 2017.
[4]	Includes Securitization Bond debt.
[5]	Amounts are included in Prepaid expenses and other current assets in the Condensed Consolidated Balance Sheets.
[6]	Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

Unconsolidated Affiliate (CenterPoint Energy and CERC) (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Sep. 04, 2018

Dec. 31, 2017

Preferred units – unconsolidated affiliate

$ 363

Percentage of sales that trigger right of first refusal

5.00%

Total distributions received from Enable

$ 83

$ 250

Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]

Equity in earnings of unconsolidated affiliate, net

208

199

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s equity method investment in Enable

2,457

2,472

Investment in unconsolidated affiliate - discontinued operations

2,472

Deferred income taxes, net - discontinued operations

927

Contribution from parent

600

Total distributions received from Enable

^[1]

223

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Income tax expense

Income from discontinued operations (net of tax of $13, $26, $44 and $75, respectively)

$ 44

$ 140

124

OGE [Member]

Percentage of sales that trigger right of first refusal

5.00%

Enable Midstream Partners [Member]

Ownership percentage of equity method investment

^[2],[3]

54.00%

Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]

Operating revenues

$ 928

705

$ 2,481

1,997

Cost of sales, excluding depreciation and amortization

516

349

1,335

936

Net income attributable to Enable common units

100

292

267

Operating income

171

137

436

399

129

104

320

301

CenterPoint Energy’s interest

173

163

Basis difference amortization (1)

^[4]

Equity in earnings of unconsolidated affiliate, net

$ 208

199

Basis difference amortization period

31 years

Equity Method Investment, Summarized Financial Information, Assets and Liabilities [Abstract]

Current assets

481

$ 481

416

Non-current assets

11,454

11,177

Current liabilities

1,403

1,279

Non-current liabilities

2,964

2,660

Non-controlling interest

Preferred equity

362

Enable partners’ equity

7,195

7,280

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]

CenterPoint Energy’s ownership interest in Enable partners’ equity

3,883

3,935

CenterPoint Energy’s basis difference

(1,426)

(1,463)

CenterPoint Energy’s equity method investment in Enable

2,457

2,472

Enable Midstream Partners [Member] | Common Units [Member]

Distributions received from Enable equity method investment

^[5]

223

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

Distributions received from Enable cost method investment

^[6]

$ 9

$ 27

Common Units [Member] | Enable Midstream Partners [Member]

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

^[3]

233,856,623

Transitional Service [Member] | Enable Midstream Partners [Member]

Preferred Units Held

^[3],[7]

14,520,000

^[8]

$ 1

$ 4

Transactions with Enable [Abstract]

Accounts receivable for amounts billed for transition services (CenterPoint Energy)

Natural Gas Expenses [Member] | Enable Midstream Partners [Member]

Transactions with Enable [Abstract]

Natural gas expenses, including transportation and storage costs (CenterPoint Energy and CERC)

Accounts payable for natural gas purchases from Enable (CenterPoint Energy and CERC)

$ 8

Enable Midstream Partners [Member]

Limited partner ownership interest

^[2]

100.00%

Maximum incentive distribution right

50.00%

Enable Midstream Partners [Member] | OGE [Member]

Limited partner ownership interest

^[2]

25.60%

Enable Midstream Partners [Member] | Public unitholders [Member]

Limited partner ownership interest

^[2]

20.40%

Enable Midstream Partners [Member] | Minimum [Member]

Incentive distribution per unit

$ 0.2875

Enable Midstream Partners [Member] | Maximum [Member]

Incentive distribution per unit

$ 0.330625

Enable Midstream Partners [Member] | Common Units [Member]

Enable Midstream Partners [Member] | Common Units [Member] | OGE [Member]

433,216,156

Enable Midstream Partners [Member] | Common Units [Member] | Public unitholders [Member]

110,982,805

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

88,376,728

Management rights ownership percentage

^[9],[10]

50.00%

Incentive distribution right

^[10],[11]

40.00%

Enable GP, LLC [Member] | OGE [Member]

Management rights ownership percentage

^[9]

50.00%

Incentive distribution right

^[11]

60.00%

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

Investment in unconsolidated affiliate - discontinued operations

$ 0

^[12]

$ 0

^[12]

$ 2,400

$ 2,472

^[12]

Deferred income taxes, net - discontinued operations

$ 974

Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]

Equity in earnings of unconsolidated affiliate, net

184

199

Income tax expense

Income from discontinued operations (net of tax of $13, $26, $44 and $75, respectively)

$ 44

$ 42

$ 140

$ 124

Common Units [Member] | Enable Midstream Partners [Member]

Enable common units distributions paid (per unit)

$ 0.318

$ 0.954

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

Enable common units distributions paid (per unit)

$ 0.625

$ 1.875

[1]	On September 4, 2018, CERC completed the Internal Spin. After such date, CNP Midstream owned the Enable common units previously owned by CERC.
[2]	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.
[3]	Includes Enable Series A Preferred Units held directly by CenterPoint Energy and common units held indirectly through CNP Midstream.
[4]	Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s original investment in Enable and their underlying equity in Enable’s net assets. The basis difference is amortized over approximately 31 years, the average life of the assets to which the basis difference is attributed.
[5]	Reflects cash distributions of $0.318 and $0.954 per common unit for the three and nine months ended September 30, 2018 and 2017, respectively.
[6]	Reflects cash distributions of $0.625 and $1.875 per Enable Series A Preferred Unit for the three and nine months ended September 30, 2018 and 2017, respectively.
[7]	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both September 30, 2018 and December 31, 2017. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods. See Note 2 for further discussion.
[8]	Represents amounts billed under the Transition Agreements for certain support services provided to Enable. Actual transition services costs are recorded net of reimbursement.
[9]	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.
[10]	Includes interests held through CNP Midstream.
[11]	Enable is expected to pay a minimum quarterly distribution of $0.2875 per common unit on its outstanding common units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to Enable GP and its affiliates, within 60 days after the end of each quarter. If cash distributions to Enable’s unitholders exceed $0.330625 per common unit in any quarter, Enable GP will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances Enable GP will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election. To date, no incentive distributions have been made.
[12]	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 9.

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

3 Months Ended

9 Months Ended

12 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

$ 867

105

(38)

(31)

Amortization expense of intangible assets

$ 2

$ 5

746

Accumulated goodwill impairment charge recorded in 2012

^[1]

110

252

Other Operations [Member]

Customer Relationships [Member]

$ 11

Intangible asset useful lives

15 years

$ 86

(26)

(21)

Noncompete Agreements [Member]

$ 60

$ 65

Intangible asset useful lives

4 years

$ 4

(2)

Other Intangible Assets [Member]

(10)

(8)

$ 5

$ 7

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

Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) (Details) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2018 USD ($) shares $ / shares	Sep. 30, 2017 USD ($)	Jun. 14, 2018 $ / shares shares	Jan. 31, 2018 $ / shares	Dec. 31, 2017 shares	Nov. 26, 2017 $ / shares
Cash paid per share exchanged \| $ / shares	$ 72.00
Distribution To ZENS holders	$ 398	$ 0
Subordinated Debt ZENS [Member]
Principal amount of debt issued	1,000
Outstanding debt balance	$ 828
Subordinated note cash exchangeable percentage of fair value	95.00%
Contingent principal amount outstanding	$ 98
AT&T To Acquire Time Warner [Member]
Distribution To ZENS holders	382
Indexed debt – reduction	(95)
Indexed debt securities derivative – reduction	(45)
Loss on indexed debt securities	242
Meredith to acquire Time [Member]
Distribution To ZENS holders	16
Indexed debt – reduction	(4)
Indexed debt securities derivative – reduction	(1)
Loss on indexed debt securities	$ 11
AT&T Common [Member]
Balance of investment owned (in shares) \| shares	10,212,945
AT&T Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note \| shares	0.7185
AT&T Common [Member] \| AT&T To Acquire Time Warner [Member]
Cash paid per share exchanged \| $ / shares			$ 53.75
Fractional shares exchanged for each TW Common share held \| shares			1.437
Cash proceeds received for shares exchanged	$ 382
Total AT&T shares received in exchange for TW Common shares held \| shares			10,212,945
Charter Common [Member]
Balance of investment owned (in shares) \| shares	872,503				872,503
Charter Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note \| shares	0.061382				0.061382
Time Common [Member]
Balance of investment owned (in shares) \| shares					888,392
ZENS early exchange ratio				100.00%
Time Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note \| shares					0.0625
Time Common [Member] \| Meredith to acquire Time [Member]
Cash paid per share exchanged \| $ / shares				$ 18.50		$ 18.50
Cash proceeds received for shares exchanged	$ 16
TW Common [Member]
Balance of investment owned (in shares) \| shares					7,107,130
TW Common [Member] \| Subordinated Debt ZENS [Member]
Number of shares referenced in exchangeable subordinated note \| shares					0.5

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

9 Months Ended

Oct. 05, 2018

USD ($)

Mar. 26, 2018

USD ($)

Feb. 28, 2018

USD ($)

Sep. 30, 2018

USD ($)

Dec. 31, 2017

USD ($)

Short-term Debt [Line Items]

Short-term borrowings

$ 0

$ 39,000,000

2,900,000,000

Parent Company [Member]

Temporary increased line of credit facility, maximum borrowing capacity

1,700,000,000

^[1]

1,700,000,000

3,300,000,000

General mortgage bonds used as collateral

300,000,000

118,000,000

Short-term Debt [Line Items]

Short-term borrowings

39,000,000

Revolving Credit Facility [Member]

900,000,000

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

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

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

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

$ 0

Percentage on limitation of debt to total capitalization under covenant

65.00%

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

70.00%

Ratio of indebtedness to net capital

^[2]

0.475

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)

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

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

Basis spread on LIBOR

^[3]

1.25%

Percentage on limitation of debt to total capitalization under covenant

^[4]

65.00%

Ratio of indebtedness to net capital

^[2]

0.507

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

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

Basis spread on LIBOR

^[3]

1.125%

Percentage on limitation of debt to total capitalization under covenant

65.00%

Ratio of indebtedness to net capital

^[2]

0.486

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

Letter of Credit [Member]

Basis spread on LIBOR

^[3]

1.125%

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

$ 11,000,000

11,000,000

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

6,000,000

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

4,000,000

Commercial Paper [Member]

1,000,000

Commercial Paper [Member] | Parent Company [Member]

202,000,000

1,753,000,000

Weighted average interest rate of debt

$ 104,000,000

$ 855,000,000

2.42%

1.88%

Commercial Paper [Member] | Houston Electric [Member]

Commercial Paper [Member] | CERC Corp [Member]

$ 0

Weighted average interest rate of debt

$ 98,000,000

$ 898,000,000

2.43%

1.72%

General Mortgage Bonds Due 2048 [Member] | Houston Electric [Member]

$ 400,000,000

3.95%

Senior Notes Due 2023 [Member] | CERC Corp [Member]

Mar. 01, 2048

$ 300,000,000

3.55%

Senior Notes Due 2028 [Member] | CERC Corp [Member]

Apr. 01, 2023

$ 300,000,000

4.00%

Merger Agreement with Vectren [Member] | Parent Company [Member]

Apr. 01, 2028

Temporary increased line of credit facility, maximum borrowing capacity

$ 3,300,000,000

Merger Agreement with Vectren [Member] | Line of Credit [Member] | Parent Company [Member]

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

^[4],[5]

75.00%

Subsequent Event [Member]

Subsequent Event [Member] | Senior Notes Due 2021 [Member]

$ 1,500,000,000

$ 500,000,000

3.60%

Subsequent Event [Member] | Senior Notes Due 2024 [Member]

Nov. 01, 2021

$ 500,000,000

3.85%

Subsequent Event [Member] | CNP Senior Notes Due 2028 [Member]

Feb. 01, 2024

$ 500,000,000

4.25%

Product Financing Arrangement [Member]

Nov. 01, 2028

Short-term Debt [Line Items]

Short-term borrowings

$ 0

$ 39,000,000

Senior Notes Redemption Period One [Member] | Subsequent Event [Member] | CNP Senior Notes [Member]

Debt instrument redemption price (percentage)

101.00%

Senior Notes Redemption Period Two [Member] | Subsequent Event [Member] | CNP Senior Notes [Member]

Debt instrument redemption price (percentage)

101.00%

[1]	Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility increased to $3.3 billion on October 5, 2018 as a result of the satisfaction of certain conditions described above.
[2]	As defined in the revolving credit facility agreement, excluding Securitization Bonds.
[3]	Based on current credit ratings.
[4]	For CenterPoint Energy (whenever its financial covenant limit is 65%) 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.
[5]	On October 5, 2018, CenterPoint Energy’s financial covenant limit returned to 65% due to the termination of all commitments in respect of the Bridge Facility without any borrowing thereunder.

Income Taxes (Details)

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Effective income tax rate

^[1]

24.00%

37.00%

26.00%

36.00%

Federal statutory income tax rate

21.00%

35.00%

Effective income tax rate

^[2]

20.00%

35.00%

21.00%

36.00%

Effective income tax rate

5.00%

^[3]

20.00%

^[3]

29.00%

^[4]

38.00%

^[4]

Effective income tax rate - discontinued operations

^[5]

23.00%

38.00%

24.00%

38.00%

State and Local Jurisdiction [Member]

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

5.00%

7.00%

18.00%

22.00%

EDIT [Member]

EDIT [Member] | Houston Electric [Member]

5.00%

4.00%

EDIT [Member] | CERC Corp [Member]

2.00%

15.00%

20.00%

[1]	CenterPoint Energy’s lower effective tax rate for the three and nine months ended September 30, 2018 compared to the same periods for 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 5% and 4%, respectively, for the three and nine months ended September 30, 2018 due to the amortization of EDIT. These decreases were partially offset by an increase to the effective tax rate of 5% for the three-month period ended September 30, 2018 as a result of the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. The effective tax rate increased by 7% for the nine-month period ended September 30, 2018 due to state law changes and the state valuation allowance. See Note 9 for further discussion on the Internal Spin.
[2]	Houston Electric’s lower effective tax rate for the three and nine months ended September 30, 2018 compared to the same periods for 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate was further reduced by 2% for both periods due to the amortization of EDIT.
[3]	CERC’s lower effective tax rate on the loss from continuing operations for the three months ended September 30, 2018 compared to the same period in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 18% due to state taxes as a result of the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. These decreases were partially offset by an increase to the effective tax rate of 15% due to the amortization of EDIT. See Note 9 for further discussion on the Internal Spin.
[4]	CERC’s lower effective tax rate on income from continuing operations for the nine months ended September 30, 2018 compared to the same period in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. The effective tax rate decreased by 20% due to the amortization of EDIT. These decreases were partially offset by an increase to the effective tax rate of 22% as a result of an increase in state tax rates and the establishment of a state valuation allowance on certain net operating loss deferred tax assets that are no longer expected to be utilized prior to expiration after the Internal Spin. See Note 9 for further discussion on the Internal Spin.
[5]	CERC’s lower effective tax rate on income from discontinued operations for the three and nine months ended September 30, 2018 compared to the same periods in 2017 was primarily due to the reduction in the federal corporate income tax rate from 35% to 21% effective January 1, 2018 as prescribed by the TCJA. See Note 9 for further discussion on the Internal Spin and the associated discontinued operations presentation.

Commitments and Contingencies (Details)	9 Months Ended
Commitments and Contingencies (Details)	Sep. 30, 2018 USD ($)
CERC Corp [Member] \| Minnesota Service Territory [Member]
Legal, Environmental and Other Matters
Liability recorded for remediation of Minnesota sites	$ 7,000,000
CERC Corp [Member] \| Minnesota Service Territory [Member] \| Minimum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 4,000,000
Years to resolve contingency	30 years
CERC Corp [Member] \| Minnesota Service Territory [Member] \| Maximum [Member]
Legal, Environmental and Other Matters
Estimated remediation costs for the Minnesota sites	$ 30,000,000
Years to resolve contingency	50 years
Natural Gas Supply Commitments [Member]
Natural Gas Supply Commitments
Remaining three months of 2018	$ 88,000,000
2019	325,000,000
2020	303,000,000
2021	219,000,000
2022	183,000,000
2023 and beyond	1,644,000,000
Minnehaha Academy Gas Explosion [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000

Earnings Per Share (CenterPoint Energy) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income available to common shareholders	$ 153	$ 169	$ 243	$ 496
Basic weighted average common shares outstanding	431,554,000	431,026,000	431,437,000	430,939,000
Plus: Incremental shares from assumed conversions:
Diluted weighted average common shares	434,891,000	434,086,000	434,774,000	433,999,000
Basic earnings per common share
Basic earnings per common share	$ 0.35	$ 0.39	$ 0.56	$ 1.15
Diluted earnings per common share
Diluted earnings per common share	$ 0.35	$ 0.39	$ 0.56	$ 1.14
Restricted Stock [Member]
Plus: Incremental shares from assumed conversions:
Restricted stock	3,337,000	3,060,000	3,337,000	3,060,000

Reportable Business Segments (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Sep. 04, 2018

Dec. 31, 2017

$ 2,212

$ 2,098

$ 7,553

$ 6,976

Equity in earnings from investment in Enable

226

297

664

828

208

199

22,228

$ 22,736

Electric Transmission and Distribution [Member]

1,994

2,477

^[1]

897

843

2,502

2,234

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

227

254

523

511

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

213

221

543

540

192

172

402

390

2,032

1,767

166

235

910

861

3,008

2,964

Midstream Investments [Member]

(9)

(20)

^[2]

Equity in earnings from investment in Enable

^[2]

208

199

Other Operations [Member]

Intersegment Eliminations [Member]

(5)

(18)

(83)

(58)

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

(681)

(654)

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

Intersegment Eliminations [Member] | Energy Services [Member]

(8)

(26)

(24)

Intersegment Eliminations [Member] | Midstream Investments [Member]

(10)

(57)

(34)

Intersegment Eliminations [Member] | Other Operations [Member]

^[2]

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

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

10,436

10,292

Operating Segments [Member] | Energy Services [Member]

6,557

6,608

Operating Segments [Member] | Midstream Investments [Member]

1,253

1,521

Operating Segments [Member] | Other Operations [Member]

2,457

2,472

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

^[3]

2,206

2,497

566

600

1,312

1,251

5,040

4,731

(7)

146

289

Assets of discontinued operations

7,305

10,112

2,472

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

230

311

402

390

2,032

1,767

CERC Corp [Member] | Energy Services [Member]

166

235

910

861

3,008

2,964

CERC Corp [Member] | Other Operations [Member]

(9)

(20)

CERC Corp [Member] | Intersegment Eliminations [Member]

(1)

(4)

(18)

(83)

(58)

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

(615)

(559)

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

(8)

(26)

(24)

CERC Corp [Member] | Intersegment Eliminations [Member] | Other Operations [Member]

(10)

(57)

(34)

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

$ 0

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

6,557

6,608

CERC Corp [Member] | Operating Segments [Member] | Midstream Investments [Member]

1,253

1,521

CERC Corp [Member] | Operating Segments [Member] | Other Operations [Member]

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

110

Assets of discontinued operations

$ 0

^[4]

$ 0

^[4]

$ 2,400

$ 2,472

^[4]

[1]	CenterPoint Energy’s and Houston Electric’s Electric Transmission & Distribution revenues from major customers are as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 (in millions)Affiliates of NRG $213 $221 $543 $540Affiliates of Vistra Energy Corp. 79 72 192 172
[2]	CenterPoint Energy’s Midstream Investments’ equity earnings, net are as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 (in millions)Enable $81 $68 $208 $199
[3]	Includes pension and other postemployment-related regulatory assets of $566 million and $600 million, respectively, as of September 30, 2018 and December 31, 2017.
[4]	On September 4, 2018, CERC completed the Internal Spin. For further information regarding the Internal Spin, see Note 9.

Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Interest, net of capitalized interest			$ 301	$ 306
Income taxes, net			89	14
Accounts payable related to capital expenditures			140	111
Capital distribution associated with the Internal Spin			0	0
Cash and cash equivalents	$ 293		293		$ 260
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	331	$ 233	331	233	296	$ 381
Prepaid expenses and other current assets [Member]
Restricted cash	37		37		35
Other [Member]
Restricted cash	1		1		1
Houston Electric [Member]
Interest, net of capitalized interest			173	176
Income taxes, net			122	76
Accounts payable related to capital expenditures			87	70
Capital distribution associated with the Internal Spin	0	0	0	0
Cash and cash equivalents	279		279		238
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	317	240	317	240	274	381
Houston Electric [Member] \| Prepaid expenses and other current assets [Member]
Restricted cash	37		37		35
Houston Electric [Member] \| Other [Member]
Restricted cash	1		1		1
CERC Corp [Member]
Interest, net of capitalized interest			85	86
Income taxes, net			3	4
Accounts payable related to capital expenditures			66	53
Capital distribution associated with the Internal Spin	1,460	0	1,460	0
Cash and cash equivalents	$ 1	$ 1	$ 1	$ 1	$ 12	$ 1

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

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

Capital distribution to parent associated with the Internal Spin

$ 0

Interest income (expense) (1)

^[1]

$ 1

Cash dividends paid to parent

123

Cash contribution from parent

Capital distribution to parent associated with the Internal Spin

Houston Electric [Member] | Operation and maintenance expense [Member]

Net affiliate service charges (billings)

(3)

(1)

(8)

(6)

Houston Electric [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]

Corporate service charges

138

127

Interest income (expense) (1)

^[1]

(2)

(4)

Cash dividends paid to parent

286

337

Cash contribution from parent

600

Capital distribution to parent associated with the Internal Spin

1,460

CERC Corp [Member] | Operation and maintenance expense [Member]

Net affiliate service charges (billings)

CERC Corp [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]

Corporate service charges

$ 36

$ 30

$ 105

$ 93

Investments [Member] | Houston Electric [Member]

Weighted average interest rate

2.45%

1.90%

Investments [Member] | CERC Corp [Member]

Weighted average interest rate

2.45%

1.90%

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

Money pool investments (borrowings) (1)

^[2]

$ (75)

$ (60)

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

Money pool investments (borrowings) (1)

^[2]

$ 0

$ (570)

[1]	Interest income is included in Other, net and interest expense is included in Interest and other finance charges on the Condensed Statements of Consolidated Income.
[2]	Included in Accounts and notes receivable (payable)–affiliated companies in the Condensed Consolidated Balance Sheets.

Equity (CenterPoint Energy) (Details)

3 Months Ended

9 Months Ended

Oct. 23, 2018

$ / shares

Oct. 01, 2018

USD ($)

day

$ / shares

Aug. 22, 2018

USD ($)

day

$ / shares

Dec. 13, 2017

$ / shares

Sep. 30, 2018

USD ($)

$ / shares

Sep. 30, 2017

$ / shares

Sep. 30, 2018

USD ($)

$ / shares

Sep. 30, 2017

USD ($)

$ / shares

Dec. 31, 2017

USD ($)

$ / shares

Dividends Declared Per Share

$ 0.2775

$ 0.2675

$ 0.5550

^[1]

$ 0.8025

Proceeds from issuance of Series A Preferred Stock, net | $

$ 790,000,000

$ 0

Series A Preferred Stock [Member]

Preferred stock par value (in dollars per share)

800,000

$ 1,000

$ 0.01

$ 0

Preferred stock liquidation preference | $

$ 800,000,000

$ 800,000

$ 0

Preferred stock liquidation preference (per share)

$ 1,000

Preferred stock dividend rate

6.125%

Preferred stock redemption price (per share)

$ 1,000

Preferred stock convertible threshold (in days) | day

120

Subsequent Event [Member] | Series B Preferred Stock [Member]

Preferred stock liquidation preference | $

$ 978,000,000

Preferred stock liquidation preference (per share)

$ 1,000

Preferred Stock, Convertible, Conversion Price

$ 1,000

Preferred stock dividend rate

7.00%

Proceeds from issuance of Series B Preferred Stock | $

$ 950,000,000

Conversion rate per share

0.05

Preferred Stock, Convertible, Threshold Consecutive Calendar Days | day

Subsequent Event [Member] | Depositary Share [Member]

Number of depositary shares eligible for conversion (in shares) | shares

19,550,000

Preferred Stock, Convertible, Conversion Price

$ 50

Subsequent Event [Member] | Common Stock [Member]

Dividends Declared Per Share

$ 0.2775

Common stock issued per share price

69,633,027

$ 27.25

Proceeds from issuance of common stock | $

$ 1,844,000,000

Plus LIBOR Spread [Member] | Series A Preferred Stock [Member]

Preferred stock dividend rate

3.27%

Minimum [Member] | Subsequent Event [Member] | Series B Preferred Stock [Member]

Convertible Preferred Stock, Shares Issued upon Conversion | shares

30.5820

Minimum [Member] | Subsequent Event [Member] | Series B Depositary Shares [Member]

$ 27.2494

Minimum [Member] | Subsequent Event [Member] | Depositary Share [Member]

$ 27.2494

Convertible Preferred Stock, Shares Issued upon Conversion | shares

1.5291

Maximum [Member] | Subsequent Event [Member] | Series B Preferred Stock [Member]

Convertible Preferred Stock, Shares Issued upon Conversion | shares

36.6980

Maximum [Member] | Subsequent Event [Member] | Series B Depositary Shares [Member]

$ 32.6990

Maximum [Member] | Subsequent Event [Member] | Depositary Share [Member]

$ 32.6990

Convertible Preferred Stock, Shares Issued upon Conversion | shares

1.8349

Over-Allotment Option [Member] | Subsequent Event [Member] | Series B Depositary Shares [Member]

Over-Allotment Option [Member] | Subsequent Event [Member] | Common Stock [Member]

2,550,000

120 Days After Conclusion of Review or Appeal [Member] | Series A Preferred Stock [Member]

9,082,568

Preferred stock redemption price (per share)

$ 1,020

Preferred stock redemption percentage of liquidation value

102.00%

[1]	On December 13, 2017, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of Common Stock, payable on March 8, 2018 to shareholders of record as of the close of business on February 15, 2018.

Subsequent Events (CenterPoint Energy and CERC) (Details)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Nov. 06, 2018

USD ($)

$ / shares

Oct. 23, 2018

$ / shares

Oct. 01, 2018

Dec. 13, 2017

$ / shares

Sep. 30, 2018

$ / shares

Sep. 30, 2017

$ / shares

Sep. 30, 2018

$ / shares

^[1]

Sep. 30, 2017

$ / shares

Oct. 05, 2018

USD ($)

Quarterly cash dividend/distribution declared per share

$ 0.2775

$ 0.2675

$ 0.5550

$ 0.8025

Subsequent Event [Member]

Aggregate principal amount of debt issued | $

$ 1,500

Subsequent Event [Member] | Common Units [Member]

Dividends payable, date declared

Oct. 23, 2018

Quarterly cash dividend/distribution declared per share

$ 0.2775

Dividends payable, date to be paid

Dec. 13, 2018

Dividends payable, date of record

Nov. 15, 2018

Subsequent Event [Member] | Series B Preferred Stock [Member]

Dividends payable, date declared

Oct. 23, 2018

Dividends payable, date to be paid

Dec. 01, 2018

Dividends payable, date of record

Nov. 15, 2018

Preferred stock dividends declared per share

$ 11.6667

Depositary share interest in a share of Series B Preferred Stock

0.05

Subsequent Event [Member] | Series B Depositary Shares [Member]

Preferred stock dividends declared per share

$ 0.5833

Subsequent Event [Member] | Enable Midstream Partners [Member] | Common Units [Member]

Expected cash distribution from equity method investment | $

$ 74

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

Expected cash distribution from cost method investment | $

$ 9

Common Units [Member] | Subsequent Event [Member] | Enable Midstream Partners [Member]

Quarterly Cash Distribution, Declaration Date

Nov. 06, 2018

Quarterly Cash Distribution, Distributions Declared, Per Unit

$ 0.318

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