10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

__________________

FORM 10-Q

(Mark One)
þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2018

OR

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

	Registrant, State or Other Jurisdiction of Incorporation or Organization
Commission file number	Address of Principal Executive Offices, Zip Code and Telephone Number	I.R.S. Employer Identification No.
1-31447	CenterPoint Energy, Inc.	74-0694415
	(a Texas corporation)
	1111 Louisiana
	Houston, Texas 77002
	(713-207-1111)
1-3187	CenterPoint Energy Houston Electric, LLC	22-3865106
	(a Texas limited liability company)
	1111 Louisiana
	Houston, Texas 77002
	(713-207-1111)
1-13265	CenterPoint Energy Resources Corp.	76-0511406
	(a Delaware corporation)
	1111 Louisiana
	Houston, Texas 77002
	(713-207-1111)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

CenterPoint Energy, Inc.            Yes þ  No o

CenterPoint Energy Houston Electric, LLC    Yes þ  No o

CenterPoint Energy Resources Corp.        Yes þ  No o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

CenterPoint Energy, Inc.            Yes þ  No o

CenterPoint Energy Houston Electric, LLC    Yes þ  No o

CenterPoint Energy Resources Corp.        Yes þ  No o

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

CenterPoint Energy, Inc.	Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o	Emerging growth company o
CenterPoint Energy Houston Electric, LLC	Large accelerated filer o	Accelerated filer o	Non-accelerated filer þ	Smaller reporting company o	Emerging growth company o
CenterPoint Energy Resources Corp.	Large accelerated filer o	Accelerated filer o	Non-accelerated filer þ	Smaller reporting company o	Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

CenterPoint Energy, Inc.            Yes o  No þ

CenterPoint Energy Houston Electric, LLC    Yes o  No þ

CenterPoint Energy Resources Corp.        Yes o  No þ

Indicate the number of shares outstanding of each of the issuers’ classes of common stock as of July 23, 2018:

CenterPoint Energy, Inc.	431,553,691 shares of common stock outstanding, excluding 166 shares held as treasury stock
CenterPoint Energy Houston Electric, LLC	1,000 common shares outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.
CenterPoint Energy Resources Corp.	1,000 shares of common stock outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.

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

Except as discussed in the last paragraph in Note 12 to the Registrants’ Condensed Consolidated Financial Statements, no registrant has an obligation in respect of any other Registrant’s debt securities, and holders of such debt securities should not consider the financial resources or results of operations of any Registrant other than the obligor in making a decision with respect to such securities.

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

TABLE OF CONTENTS

PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	CenterPoint Energy, Inc. Financial Statements (unaudited)	1
	CenterPoint Energy Houston Electric, LLC Financial Statements (unaudited)	6
	CenterPoint Energy Resources Corp. Financial Statements (unaudited)	11
	Combined Notes to Unaudited Condensed Consolidated Financial Statements	16
	(1) Background and Basis of Presentation	16
	(2) New Accounting Pronouncements	17
	(3) Proposed Merger with Vectren	19
	(4) Revenue Recognition	20
	(5) Employee Benefit Plans	22
	(6) Regulatory Accounting	24
	(7) Derivative Instruments	25
	(8) Fair Value Measurements	28
	(9) Unconsolidated Affiliate	30
	(10) Goodwill and Other Intangibles	33
	(11) Indexed Debt Securities (ZENS) and Securities Related to ZENS	33
	(12) Short-term Borrowings and Long-term Debt	34
	(13) Income Taxes	36
	(14) Commitments and Contingencies	36
	(15) Earnings Per Share	38
	(16) Reportable Business Segments	39
	(17) Supplemental Disclosure of Cash Flow Information	41
	(18) Related Party Transactions	42
	(19) Subsequent Events	42
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	43
	Recent Events	43
	Consolidated Results of Operations	44
	Results of Operations by Business Segment	48
	Certain Factors Affecting Future Earnings	54
	Liquidity and Capital Resources	55
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	64
Item 4.	Controls and Procedures	65
PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	65
Item 1A.	Risk Factors	65
Item 5.	Other Information	66
Item 6.	Exhibits	66
	Signatures	69

i

GLOSSARY
AEM	Atmos Energy Marketing, LLC, previously a wholly-owned subsidiary of Atmos Energy Holdings, Inc., a wholly-owned subsidiary of Atmos Energy Corporation
AMA	Asset Management Agreement
AMS	Advanced Metering System
APSC	Arkansas Public Service Commission
ARAM	Average rate assumption method
ARP	Alternative revenue program
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
AT&T	AT&T Inc.
AT&T Common	AT&T common stock
Bcf	Billion cubic feet
Bond Companies	Bond Company II, Bond Company III, Bond Company IV and Restoration Bond Company, each a wholly-owned, bankruptcy remote entity formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of Securitization Bonds
Bond Company II	CenterPoint Energy Transition Bond Company II, LLC, a wholly-owned subsidiary of Houston Electric
Bond Company III	CenterPoint Energy Transition Bond Company III, LLC, a wholly-owned subsidiary of Houston Electric
Bond Company IV	CenterPoint Energy Transition Bond Company IV, LLC, a wholly-owned subsidiary of Houston Electric
Brazos Valley Connection	A portion of the Houston region transmission project between Houston Electric’s Zenith substation and the Gibbons Creek substation owned by the Texas Municipal Power Agency
Bridge Facility	A $5 billion 364-day senior unsecured bridge term loan facility
CenterPoint Energy	CenterPoint Energy, Inc., and its subsidiaries
CERC Corp.	CenterPoint Energy Resources Corp.
CERC	CERC Corp., together with its subsidiaries
CES	CenterPoint Energy Services, Inc., a wholly-owned subsidiary of CERC Corp.
Charter Common	Charter Communications, Inc. common stock
CIP	Conservation Improvement Program
COLI	Corporate-owned life insurance
Continuum	The retail energy services business of Continuum Retail Energy Services, LLC, including its wholly-owned subsidiary Lakeshore Energy Services, LLC and the natural gas wholesale assets of Continuum Energy Services, LLC
DCRF	Distribution Cost Recovery Factor
EDIT	Excess deferred income taxes
EECR	Energy Efficiency Cost Recovery
EECRF	Energy Efficiency Cost Recovery Factor
Enable	Enable Midstream Partners, LP
EPA	Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
FCC	Federal Communications Commission
FERC	Federal Energy Regulatory Commission
Fitch	Fitch, Inc.
Form 10-Q	Quarterly Report on Form 10-Q
FRP	Formula Rate Plan

ii

GLOSSARY
FTC	Federal Trade Commission
Gas Daily	Platts gas daily indices
GenOn	GenOn Energy, Inc.
GRIP	Gas Reliability Infrastructure Program
GWh	Gigawatt-hours
Houston Electric	CenterPoint Energy Houston Electric, LLC and its subsidiaries
HSR	Hart-Scott-Rodino
Interim Condensed Financial Statements	Unaudited condensed consolidated interim financial statements and combined notes
IRS	Internal Revenue Service
kV	Kilovolt
LIBOR	London Interbank Offered Rate
Meredith	Meredith Corporation
Merger	The merger of Merger Sub with and into Vectren on the terms and subject to the conditions set forth in the Merger Agreement, with Vectren continuing as the surviving corporation and as a wholly-owned subsidiary of CenterPoint Energy, Inc.
Merger Agreement	Agreement and Plan of Merger, dated as of April 21, 2018, among CenterPoint Energy, Vectren and Merger Sub
Merger Sub	Pacer Merger Sub, Inc., an Indiana corporation and wholly-owned subsidiary of CenterPoint Energy
MGP	Manufactured gas plant
MLP	Master Limited Partnership
MMBtu	One million British thermal units
Moody’s	Moody’s Investors Service, Inc.
MPSC	Mississippi Public Service Commission
MPUC	Minnesota Public Utilities Commission
NGD	Natural gas distribution business
NGLs	Natural gas liquids
NOPR	Notice of Proposed Rulemaking
NRG	NRG Energy, Inc.
NYMEX	New York Mercantile Exchange
NYSE	New York Stock Exchange
OCC	Oklahoma Corporation Commission
OGE	OGE Energy Corp.
PBRC	Performance Based Rate Change
PRPs	Potentially responsible parties
PUCT	Public Utility Commission of Texas
Railroad Commission	Railroad Commission of Texas
Registrants	CenterPoint Energy, Houston Electric and CERC, collectively
Reliant Energy	Reliant Energy, Incorporated
REP	Retail electric provider
Restoration Bond Company	CenterPoint Energy Restoration Bond Company, LLC, a wholly-owned subsidiary of Houston Electric
Revised Policy Statement	Revised Policy Statement on Treatment of Income Taxes
ROE	Return on equity
RRA	Rate Regulation Adjustment
RRI	Reliant Resources, Inc.
RSP	Rate Stabilization Plan
SEC	Securities and Exchange Commission

iii

GLOSSARY
Securitization Bonds	Transition and system restoration bonds
Series A Preferred Units	Enable’s 10% Series A Fixed-to-Floating Non-Cumulative Redeemable Perpetual Preferred Units, representing limited partner interests in Enable
S&P	Standard & Poor’s Ratings Services, a division of The McGraw-Hill Companies
TBD	To be determined
TCEH Corp.	Formerly Texas Competitive Electric Holdings Company LLC, predecessor to Vistra Energy Corp. whose major subsidiaries include Luminant and TXU Energy
TCJA	Tax reform legislation informally called the Tax Cuts and Jobs Act of 2017
TCOS	Transmission Cost of Service
TDU	Transmission and distribution utility
Time	Time Inc.
Time Common	Time common stock
Transition Agreements	Services Agreement, Employee Transition Agreement, Transitional Seconding Agreement and other agreements entered into in connection with the formation of Enable
TW	Time Warner Inc.
TW Common	TW common stock
Vectren	Vectren Corporation, an Indiana corporation
VIE	Variable interest entity
Vistra Energy Corp.	Texas-based energy company focused on the competitive energy and power generation markets
ZENS	2.0% Zero-Premium Exchangeable Subordinated Notes due 2029
ZENS-Related Securities	As of June 30, 2018, consisted of AT&T Common and Charter Common and as of December 31, 2017, consisted of Charter Common, Time Common and TW Common
2017 Form 10-K	Annual Report on Form 10-K for the fiscal year ended December 31, 2017

iv

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

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

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

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

• the performance of Enable, the amount of cash distributions CenterPoint Energy and CERC receive from Enable, Enable’s ability to redeem the Series A Preferred Units in certain circumstances and the value of CenterPoint Energy’s and CERC’s interest in Enable, and factors that may have a material impact on such performance, cash distributions and value, including factors such as:

◦ competitive conditions in the midstream industry, and actions taken by Enable’s customers and competitors, including the extent and timing of the entry of additional competition in the markets served by Enable;

◦ the timing and extent of changes in the supply of natural gas and associated commodity prices, particularly prices of natural gas and NGLs, the competitive effects of the available pipeline capacity in the regions served by Enable, and the effects of geographic and seasonal commodity price differentials, including the effects of these circumstances on re-contracting available capacity on Enable’s interstate pipelines;

◦ the demand for crude oil, natural gas, NGLs and transportation and storage services;

◦ environmental and other governmental regulations, including the availability of drilling permits and the regulation of hydraulic fracturing;

◦ recording of non-cash goodwill, long-lived asset or other than temporary impairment charges by or related to Enable;

◦ changes in tax status;

◦ access to debt and equity capital; and

◦ the availability and prices of raw materials and services for current and future construction projects;

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

• timely and appropriate rate actions that allow recovery of costs and a reasonable return on investment;

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

• weather variations and other natural phenomena, including the impact of severe weather events on operations and capital;

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

• CenterPoint Energy’s expected timing, likelihood and benefits of completion of the Merger, including the timing, receipt and terms and conditions of any required approvals by Vectren’s shareholders and governmental and regulatory agencies or the outcome of shareholder litigation filed against Vectren that could reduce anticipated benefits or cause the parties to delay or abandon the Merger, as well as the ability to successfully integrate the businesses and realize anticipated benefits, the possibility that long-term financing for the Merger may not be put in place before the closing of the Merger or that financing terms may not be as expected and the risk that the credit ratings of the combined company or its subsidiaries may be different from what CenterPoint Energy expects;

v

• tax legislation, including the effects of the TCJA (which includes any potential changes to interest deductibility) and uncertainties involving state commissions’ and local municipalities’ regulatory requirements and determinations regarding the treatment of EDIT and our rates;

• CenterPoint Energy’s and CERC’s ability to mitigate weather impacts through normalization or rate mechanisms, and the effectiveness of such mechanisms;

• the timing and extent of changes in commodity prices, particularly natural gas, and the effects of geographic and seasonal commodity price differentials on CERC and Enable;

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

• changes in interest rates and their impact on costs of borrowing and the valuation of CenterPoint Energy’s pension benefit obligation;

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

• local, state and federal legislative and regulatory actions or developments relating to the environment, including those related to global climate change;

• the impact of unplanned facility outages;

• any direct or indirect effects on our or Enable’s facilities, operations and financial condition resulting from terrorism, cyber-attacks, data security breaches or other attempts to disrupt our businesses or the businesses of third parties, or other catastrophic events such as fires, earthquakes, explosions, leaks, floods, droughts, hurricanes, pandemic health events or other occurrences;

• our ability to invest planned capital and the timely recovery of our investment in capital;

• our ability to control operation and maintenance costs;

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

• the investment performance of CenterPoint Energy’s pension and postretirement benefit plans;

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

• changes in rates of inflation;

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

• non-payment for our services due to financial distress of our customers;

• the extent and effectiveness of our and Enable’s risk management and hedging activities, including, but not limited to financial and weather hedges and commodity risk management activities;

• timely and appropriate regulatory actions, which include actions allowing securitization, for any future hurricanes or natural disasters or other recovery of costs, including costs associated with Hurricane Harvey;

• CenterPoint Energy, CERC or Enable’s potential business strategies and strategic initiatives, including restructurings, joint ventures and acquisitions or dispositions of assets or businesses (including a reduction of CenterPoint Energy’s and CERC’s interests in Enable, if any, whether through their decision to sell all or a portion of the Enable common units they own in the public equity markets or otherwise, subject to certain limitations), which CenterPoint Energy, CERC and Enable cannot assure you will be completed or will have the anticipated benefits to us or Enable;

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

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

• the outcome of litigation;

• the ability of REPs, including REP affiliates of NRG and Vistra Energy Corp., formerly known as TCEH Corp., to satisfy their obligations to CenterPoint Energy and Houston Electric;

• the ability of GenOn (formerly known as RRI Energy, Inc., Reliant Energy and RRI), a wholly-owned subsidiary of NRG, and its subsidiaries, currently the subject of bankruptcy proceedings, to satisfy their obligations to us, including indemnity obligations;

vi

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

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

• the effective tax rates;

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

• other factors discussed in “Risk Factors” in Item 1A of Part I of each of the Registrants’ 2017 Form 10-K and in Item 1A of Part II of CenterPoint Energy’s First Quarter 2018 Form 10-Q, which are incorporated herein by reference, and other reports the Registrants file from time to time with the SEC.

You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and the Registrants undertake no obligation to update or revise any forward-looking statements. Investors should note that the Registrants announce material financial information in SEC filings, press releases and public conference calls. Based on guidance from the SEC, the Registrants may use the Investors section of CenterPoint Energy’s website (www.centerpointenergy.com) to communicate with investors about the Registrants. It is possible that the financial and other information posted there could be deemed to be material information. The information on CenterPoint Energy’s website is not part of this combined Form 10-Q.

vii

PART I. FINANCIAL INFORMATION

Item 1.     FINANCIAL STATEMENTS

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(In Millions, Except Per Share Amounts)

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2018			2017			2018			2017
Revenues:
Utility revenues	$	1,341		$	1,222		$	3,235		$	2,768
Non-utility revenues	845			921			2,106			2,110
Total	2,186			2,143			5,341			4,878
Expenses:
Utility natural gas	188			150			825			600
Non-utility natural gas	790			882			2,063			2,011
Operation and maintenance	578			518			1,147			1,061
Depreciation and amortization	342			254			656			480
Taxes other than income taxes	101			99			212			195
Total	1,999			1,903			4,903			4,347
Operating Income	187			240			438			531
Other Income (Expense):
Gain on marketable securities	22			23			23			67
Loss on indexed debt securities	(254		)	(13		)	(272		)	(23		)
Interest and other finance charges	(91		)	(77		)	(169		)	(155		)
Interest on Securitization Bonds	(14		)	(20		)	(30		)	(40		)
Equity in earnings of unconsolidated affiliate, net	58			59			127			131
Other, net	4			(1		)	7			(1		)
Total	(275		)	(29		)	(314		)	(21		)
Income (Loss) Before Income Taxes	(88		)	211			124			510
Income tax expense (benefit)	(13		)	76			34			183
Net Income (Loss)	$	(75	)	$	135		$	90		$	327
Basic Earnings (Loss) Per Share	$	(0.17	)	$	0.31		$	0.21		$	0.76
Diluted Earnings (Loss) Per Share	$	(0.17	)	$	0.31		$	0.21		$	0.75
Dividends Declared Per Share	$	0.2775		$	0.2675		$	0.2775		$	0.5350
Weighted Average Shares Outstanding, Basic	432			431			431			431
Weighted Average Shares Outstanding, Diluted	432			434			434			434

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

1

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(In Millions)

(Unaudited)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2018			2017		2018		2017
Net income (loss)	$	(75	)	$	135	$	90	$	327
Other comprehensive income:
Adjustment to pension and other postretirement plans (net of tax of $-0-, $1, $1 and $2)	2			1		3		2
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $1 and $-0-)	(1		)	—		3		(1		)
Total	1			1		6		1
Comprehensive income (loss)	$	(74	)	$	136	$	96	$	328

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

2

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Millions)

(Unaudited)

ASSETS

	June 30, 2018		December 31, 2017
Current Assets:
Cash and cash equivalents ($253 and $230 related to VIEs, respectively)	$	328	$	260
Investment in marketable securities	584		960
Accounts receivable ($112 and $73 related to VIEs, respectively), less bad debt reserve of $21 and $19, respectively	958		1,000
Accrued unbilled revenues	207		427
Natural gas inventory	152		222
Materials and supplies	192		175
Non-trading derivative assets	74		110
Taxes receivable	39		—
Prepaid expenses and other current assets ($37 and $35 related to VIEs, respectively)	167		241
Total current assets	2,701		3,395
Property, Plant and Equipment:
Property, plant and equipment	19,585		19,031
Less: accumulated depreciation and amortization	6,188		5,974
Property, plant and equipment, net	13,397		13,057
Other Assets:
Goodwill	867		867
Regulatory assets ($1,293 and $1,590 related to VIEs, respectively)	2,067		2,347
Non-trading derivative assets	46		44
Investment in unconsolidated affiliate	2,451		2,472
Preferred units – unconsolidated affiliate	363		363
Other	216		191
Total other assets	6,010		6,284
Total Assets	$	22,108	$	22,736

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

3

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(In Millions, except share amounts)

(Unaudited)

LIABILITIES AND SHAREHOLDERS’ EQUITY

	June 30, 2018			December 31, 2017
Current Liabilities:
Short-term borrowings	$	—		$	39
Current portion of VIE Securitization Bonds long-term debt	446			434
Indexed debt, net	26			122
Current portion of other long-term debt	50			50
Indexed debt securities derivative	641			668
Accounts payable	706			963
Taxes accrued	103			181
Interest accrued	118			104
Dividends accrued	—			120
Non-trading derivative liabilities	26			20
Due to ZENS note holders	382			—
Other	344			368
Total current liabilities	2,842			3,069
Other Liabilities:
Deferred income taxes, net	3,168			3,174
Non-trading derivative liabilities	12			4
Benefit obligations	723			785
Regulatory liabilities	2,521			2,464
Other	412			357
Total other liabilities	6,836			6,784
Long-term Debt:
VIE Securitization Bonds, net	1,193			1,434
Other long-term debt, net	6,567			6,761
Total long-term debt, net	7,760			8,195
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized, none issued or outstanding	—			—
Common stock, $0.01 par value, 1,000,000,000 shares authorized, 431,547,782 shares and 431,044,845 shares outstanding, respectively	4			4
Additional paid-in capital	4,215			4,209
Retained earnings	513			543
Accumulated other comprehensive loss	(62		)	(68		)
Total shareholders’ equity	4,670			4,688
Total Liabilities and Shareholders’ Equity	$	22,108		$	22,736

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

4

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(In Millions)

(Unaudited)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities:
Net income	$	90		$	327
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	656			480
Amortization of deferred financing costs	18			12
Deferred income taxes	(12		)	95
Unrealized gain on marketable securities	(23		)	(67		)
Loss on indexed debt securities	272			23
Write-down of natural gas inventory	1			—
Equity in earnings of unconsolidated affiliate, net of distributions	(9		)	(131		)
Pension contributions	(64		)	(18		)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	232			234
Inventory	52			(20		)
Taxes receivable	(39		)	30
Accounts payable	(246		)	(158		)
Fuel cost recovery	69			(12		)
Non-trading derivatives, net	64			(49		)
Margin deposits, net	(9		)	(43		)
Interest and taxes accrued	(64		)	(17		)
Net regulatory assets and liabilities	57			(34		)
Other current assets	(4		)	10
Other current liabilities	(13		)	(29		)
Other assets	(3		)	(1		)
Other liabilities	60			27
Other, net	8			18
Net cash provided by operating activities	1,093			677
Cash Flows from Investing Activities:
Capital expenditures	(697		)	(649		)
Acquisitions, net of cash acquired	—			(132		)
Distributions from unconsolidated affiliate in excess of cumulative earnings	30			149
Proceeds from sale of marketable securities	398			—
Other, net	2			(8		)
Net cash used in investing activities	(267		)	(640		)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(39		)	(11		)
Proceeds from (payments of) commercial paper, net	(1,188		)	284
Proceeds from long-term debt, net	997			298
Payments of long-term debt	(230		)	(469		)
Debt issuance costs	(35		)	(6		)
Payment of dividends on common stock	(240		)	(230		)
Distribution to ZENS note holders	(16		)	—
Other, net	(5		)	(4		)
Net cash used in financing activities	(756		)	(138		)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	70			(101		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	296			381
Cash, Cash Equivalents and Restricted Cash at End of Period	$	366		$	280

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

5

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Millions of Dollars)

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
Revenues	$	854		$	752		$	1,609		$	1,390
Expenses:
Operation and maintenance	351			343			693			684
Depreciation and amortization	262			180			495			332
Taxes other than income taxes	60			58			121			118
Total	673			581			1,309			1,134
Operating Income	181			171			300			256
Other Income (Expense):
Interest and other finance charges	(36		)	(32		)	(69		)	(65		)
Interest on Securitization Bonds	(14		)	(20		)	(30		)	(40		)
Other, net	(3		)	(2		)	(6		)	(6		)
Total	(53		)	(54		)	(105		)	(111		)
Income Before Income Taxes	128			117			195			145
Income tax expense	27			42			42			52
Net Income	$	101		$	75		$	153		$	93

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

6

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Millions of Dollars)

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
Net income	$	101	$	75	$	153	$	93
Other comprehensive income:
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $1 and $-0-)	—		—		4		(1		)
Total	—		—		4		(1		)
Comprehensive income	$	101	$	75	$	157	$	92

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

7

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

CONDENSED CONSOLIDATED BALANCE SHEETS

(Millions of Dollars)

(Unaudited)

ASSETS

	June 30, 2018		December 31, 2017
Current Assets:
Cash and cash equivalents ($253 and $230 related to VIEs, respectively)	$	253	$	238
Accounts and notes receivable ($112 and $73 related to VIEs, respectively), less bad debt reserve of $1 and $1, respectively	389		284
Accounts and notes receivable–affiliated companies	32		7
Accrued unbilled revenues	122		120
Materials and supplies	125		119
Taxes receivable	23		—
Prepaid expenses and other current assets ($37 and $35 related to VIEs, respectively)	59		62
Total current assets	1,003		830
Property, Plant and Equipment:
Property, plant and equipment	11,812		11,496
Less: accumulated depreciation and amortization	3,741		3,633
Property, plant and equipment, net	8,071		7,863
Other Assets:
Regulatory assets ($1,293 and $1,590 related to VIEs, respectively)	1,321		1,570
Other	35		29
Total other assets	1,356		1,599
Total Assets	$	10,430	$	10,292

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

8

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

CONDENSED CONSOLIDATED BALANCE SHEETS

(Millions of Dollars)

(Unaudited)

LIABILITIES AND MEMBER’S EQUITY

	June 30, 2018		December 31, 2017
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	$	446	$	434
Accounts payable	208		243
Accounts and notes payable–affiliated companies	121		104
Taxes accrued	61		116
Interest accrued	75		65
Other	93		120
Total current liabilities	1,004		1,082
Other Liabilities:
Deferred income taxes, net	1,025		1,059
Benefit obligations	143		146
Regulatory liabilities	1,265		1,263
Other	56		54
Total other liabilities	2,489		2,522
Long-term Debt:
VIE Securitization Bonds, net	1,193		1,434
Other, net	3,280		2,885
Total long-term debt, net	4,473		4,319
Commitments and Contingencies (Note 14)
Member’s Equity:
Common stock	—		—
Paid-in capital	1,697		1,696
Retained earnings	763		673
Accumulated other comprehensive income	4		—
Total member’s equity	2,464		2,369
Total Liabilities and Member’s Equity	$	10,430	$	10,292

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

9

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Millions of Dollars)

(Unaudited)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities:
Net income	$	153		$	93
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	495			332
Amortization of deferred financing costs	6			6
Deferred income taxes	(38		)	23
Changes in other assets and liabilities:
Accounts and notes receivable, net	(107		)	(63		)
Accounts receivable/payable–affiliated companies	78			(35		)
Inventory	(6		)	(1		)
Accounts payable	(6		)	57
Taxes receivable	(23		)	(38		)
Interest and taxes accrued	(45		)	(41		)
Net regulatory assets and liabilities	(59		)	(59		)
Other current assets	4			2
Other current liabilities	(11		)	(7		)
Other assets	2			4
Other liabilities	2			1
Other, net	(2		)	5
Net cash provided by operating activities	443			279
Cash Flows from Investing Activities:
Capital expenditures	(441		)	(414		)
Decrease (increase) in notes receivable–affiliated companies	(26		)	5
Other, net	(1		)	(9		)
Net cash used in investing activities	(468		)	(418		)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	398			298
Payments of long-term debt	(230		)	(219		)
Decrease in notes payable–affiliated companies	(60		)	—
Dividend to parent	(63		)	(42		)
Debt issuance costs	(4		)	(3		)
Other, net	1			1
Net cash provided by financing activities	42			35
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	17			(104		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	274			381
Cash, Cash Equivalents and Restricted Cash at End of Period	$	291		$	277

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

10

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Millions of Dollars)

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
Revenues:
Utility revenues	$	487		$	470		$	1,630		$	1,377
Non-utility revenues	841			917			2,098			2,103
Total	1,328			1,387			3,728			3,480
Expenses:
Utility natural gas	188			150			825			600
Non-utility natural gas	790			882			2,063			2,011
Operation and maintenance	217			190			455			405
Depreciation and amortization	72			68			145			134
Taxes other than income taxes	39			38			87			72
Total	1,306			1,328			3,575			3,222
Operating Income	22			59			153			258
Other Income (Expense):
Interest and other finance charges	(33		)	(31		)	(62		)	(60		)
Equity in earnings of unconsolidated affiliate, net	58			59			127			131
Other, net	(1		)	(4		)	(5		)	(9		)
Total	24			24			60			62
Income Before Income Taxes	46			83			213			320
Income tax expense	10			29			47			119
Net Income	$	36		$	54		$	166		$	201

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

11

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Millions of Dollars)

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2018		2017		2018		2017
Net income	$	36	$	54	$	166	$	201
Comprehensive income	$	36	$	54	$	166	$	201

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

12

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

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

CONDENSED CONSOLIDATED BALANCE SHEETS

(Millions of Dollars)

(Unaudited)

ASSETS

	June 30, 2018		December 31, 2017
Current Assets:
Cash and cash equivalents	$	1	$	12
Accounts receivable, less bad debt reserve of $20 and $18, respectively	566		713
Accrued unbilled revenues	85		307
Accounts and notes receivable–affiliated companies	15		6
Materials and supplies	67		56
Natural gas inventory	152		222
Non-trading derivative assets	74		110
Prepaid expenses and other current assets	80		166
Total current assets	1,040		1,592
Property, Plant and Equipment:
Property, plant and equipment	7,104		6,888
Less: accumulated depreciation and amortization	2,136		2,036
Property, plant and equipment, net	4,968		4,852
Other Assets:
Goodwill	867		867
Regulatory assets	173		181
Non-trading derivative assets	46		44
Investment in unconsolidated affiliate	2,451		2,472
Other	97		104
Total other assets	3,634		3,668
Total Assets	$	9,642	$	10,112

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

13

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

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

CONDENSED CONSOLIDATED BALANCE SHEETS

(Millions of Dollars)

(Unaudited)

LIABILITIES AND STOCKHOLDER’S EQUITY

	June 30, 2018		December 31, 2017
Current Liabilities:
Short-term borrowings	$	—	$	39
Accounts payable	434		669
Accounts and notes payable–affiliated companies	36		611
Taxes accrued	48		75
Interest accrued	38		32
Customer deposits	75		76
Non-trading derivative liabilities	26		20
Other	152		137
Total current liabilities	809		1,659
Other Liabilities:
Deferred income taxes, net	1,330		1,289
Non-trading derivative liabilities	12		4
Benefit obligations	98		97
Regulatory liabilities	1,256		1,201
Other	352		297
Total other liabilities	3,048		2,888
Long-Term Debt	2,722		2,457
Commitments and Contingencies (Note 14)
Stockholder’s Equity:
Common stock	—		—
Paid-in capital	2,528		2,528
Retained earnings	529		574
Accumulated other comprehensive income	6		6
Total stockholder’s equity	3,063		3,108
Total Liabilities and Stockholder’s Equity	$	9,642	$	10,112

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

14

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

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

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Millions of Dollars)

(Unaudited)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities:
Net income	$	166		$	201
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	145			134
Amortization of deferred financing costs	4			4
Deferred income taxes	41			115
Write-down of natural gas inventory	1			—
Equity in earnings of unconsolidated affiliate, net of distributions	(9		)	(131		)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	339			295
Accounts receivable/payable–affiliated companies	(14		)	(1		)
Inventory	58			(18		)
Accounts payable	(248		)	(203		)
Fuel cost recovery	69			(12		)
Interest and taxes accrued	(21		)	(27		)
Non-trading derivatives, net	61			(49		)
Margin deposits, net	(9		)	(43		)
Net regulatory assets and liabilities	92			(1		)
Other current assets	7			12
Other current liabilities	8			(14		)
Other assets	4			5
Other liabilities	52			10
Other, net	—			1
Net cash provided by operating activities	746			278
Cash Flows from Investing Activities:
Capital expenditures	(230		)	(223		)
Distributions from unconsolidated affiliate in excess of cumulative earnings	30			149
Acquisitions, net of cash acquired	—			(132		)
Other, net	3			1
Net cash used in investing activities	(197		)	(205		)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(39		)	(11		)
Proceeds from (payments of) commercial paper, net	(333		)	149
Proceeds from long-term debt	599			—
Dividends to parent	(211		)	(248		)
Debt issuance costs	(5		)	(1		)
Decrease in notes payable–affiliated companies	(570		)	—
Contribution from parent	—			38
Other, net	(1		)	—
Net cash used in financing activities	(560		)	(73		)
Net Decrease in Cash and Cash Equivalents	(11		)	—
Cash and Cash Equivalents at Beginning of Period	12			1
Cash and Cash Equivalents at End of Period	$	1		$	1

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

15

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

COMBINED NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1) 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. CenterPoint Energy’s operating subsidiaries, Houston Electric and CERC, own and operate electric transmission and distribution and natural gas distribution facilities, supply natural gas to commercial and industrial customers and electric and natural gas utilities and own interests in Enable as described below.

• 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 June 30, 2018, CERC Corp. owned approximately 54.0% of the common units representing limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

As of June 30, 2018, CenterPoint Energy also owned an aggregate of 14,520,000 Series A Preferred Units in Enable.

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

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

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

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

16

(2) 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 or CERC’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 Series A Preferred Units in Enable, 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 six months ended June 30, 2018 and 2017, respectively, due to the requirement that cash proceeds from COLI policies be classified as cash inflows from investing activity.
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 six months ended June 30, 2018 and 2017, respectively.

17

Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
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.

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

	Three Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	15	$	8	$	4	$	17	$	7	$	6
Decrease to other income	15		8		4		17		7		6
	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	29	$	15	$	8	$	34	$	15	$	11
Decrease to other income	29		15		8		34		15		11

18

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 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.	January 1, 2019 Early adoption is permitted	The Registrants will elect the practical expedient on existing easements provided by ASU 2018-01 and 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 2017-12- Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities	This standard expands an entity’s ability to hedge nonfinancial and financial risk components and reduce complexity in fair value hedges of interest rate risk. The guidance eliminates the requirement to separately measure and report hedge ineffectiveness, eases certain documentation and assessment requirements and updates the presentation and disclosure requirements. Transition method: cumulative-effect adjustment for elimination of the separate measurement of ineffectiveness; prospective for presentation and disclosure	January 1, 2019 Early adoption is permitted	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.
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.

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

(3) Proposed 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. CenterPoint Energy expects to finance the Merger with a combination of debt, equity-linked and equity issuances and has obtained commitments by lenders for a Bridge Facility to provide flexibility for the timing of the long-term acquisition financing and fund, in part, amounts payable by CenterPoint Energy in connection with the Merger. All outstanding debt held by Vectren and its subsidiaries will be assumed by CenterPoint Energy at the closing of the Merger. As of June 30, 2018, Vectren and its subsidiaries had outstanding $248 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 and pursuant to the HSR Act and (ii) 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 July 16, 2018, Vectren filed its definitive proxy statement, as supplemented, with the SEC for a special meeting of its shareholders to be held on August 28, 2018 in connection with the Merger.

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 and Vectren would be required to pay CenterPoint Energy a termination fee of $150 million. Subject

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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.

(4) 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 June 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	$	860		$	509		$	78		$	2	$	1,449		$	758		$	463		$	116		$	1	$	1,338
Derivatives income	—			—			782			—		782			—			—			815			—		815
Other (3)	(6		)	(14		)	—			2		(18		)	(6		)	14			—			2		10
Eliminations	—			(8		)	(19		)	—		(27		)	—			(7		)	(13		)	—		(20		)
Total revenues	$	854		$	487		$	841		$	4	$	2,186		$	752		$	470		$	918		$	3	$	2,143
	Six Months Ended June 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	$	1,621		$	1,695		$	256		$	3	$	3,575		$	1,402		$	1,388		$	258		$	2	$	3,050
Derivatives income	(4		)	—			1,889			—		1,885			1			—			1,869			—		1,870
Other (3)	(12		)	(47		)	—			5		(54		)	(12		)	5			—			5		(2		)
Eliminations	—			(18		)	(47		)	—		(65		)	—			(16		)	(24		)	—		(40		)
Total revenues	$	1,605		$	1,630		$	2,098		$	8	$	5,341		$	1,391		$	1,377		$	2,103		$	7	$	4,878

Houston Electric

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Revenue from contracts	$	860		$	758		$	1,621		$	1,402
Other (3)	(6		)	(6		)	(12		)	(12		)
	$	854		$	752		$	1,609		$	1,390

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CERC

	Three Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	509		$	78		$	—	$	587		$	463		$	116		$	—		$	579
Derivatives income	—			782			—		782			—			815			—			815
Other (3)	(14		)	—			—		(14		)	14			—			(1		)	13
Eliminations	(8		)	(19		)	—		(27		)	(7		)	(13		)	—			(20		)
Total revenues	$	487		$	841		$	—	$	1,328		$	470		$	918		$	(1	)	$	1,387
	Six Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	1,695		$	256		$	—	$	1,951		$	1,388		$	258		$	—		$	1,646
Derivatives income	—			1,889			—		1,889			—			1,869			—			1,869
Other (3)	(47		)	—			—		(47		)	5			—			—			5
Eliminations	(18		)	(47		)	—		(65		)	(16		)	(24		)	—			(40		)
Total revenues	$	1,630		$	2,098		$	—	$	3,728		$	1,377		$	2,103		$	—		$	3,480

(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

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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.

(5) Employee Benefit Plans

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

Pension Benefits (CenterPoint Energy)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Service cost (1)	$	9		$	9		$	18		$	18
Interest cost (2)	19			22			39			44
Expected return on plan assets (2)	(26		)	(24		)	(53		)	(48		)
Amortization of prior service cost (2)	2			3			4			5
Amortization of net loss (2)	11			15			22			29
Net periodic cost	$	15		$	25		$	30		$	48

Postretirement Benefits

	Three Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	4			2			1			4			2			1
Expected return on plan assets (2)	(2		)	(1		)	(1		)	(2		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(2		)	1			(1		)	(1		)	1
Net periodic cost	$	2		$	(1	)	$	1		$	2		$	—		$	2
	Six Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	7			4			2			8			4			2
Expected return on plan assets (2)	(3		)	(2		)	(1		)	(3		)	(2		)	—
Amortization of prior service cost (credit) (2)	(2		)	(3		)	1			(2		)	(2		)	1
Net periodic cost	$	3		$	(1	)	$	2		$	4		$	—		$	3

(1) Included in Operation and maintenance expense in the Registrants’ Condensed Statements of Consolidated Income.

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(2) Included in Other, net in the Registrants’ Condensed Statements of Consolidated Income.

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

CenterPoint Energy

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Beginning Balance	$	(65	)	$	(71	)	$	(66	)	$	(72	)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	1			1			1			1
Actuarial losses (1)	1			1			3			3
Tax expense	—			(1		)	(1		)	(2		)
Net current period other comprehensive income	2			1			3			2
Ending Balance	$	(63	)	$	(70	)	$	(63	)	$	(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 June 30, 2018						Six Months Ended June 30, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	2	$	—	$	—	$	64	$	—	$	—
Postretirement benefit plan	3		2		1		7		4		2

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(6) Regulatory Accounting

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

	June 30, 2018									December 31, 2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	55		$	—		$	55		$	130		$	—		$	130
Non-current regulatory assets:
Securitized regulatory assets	1,293			1,293			—			1,590			1,590			—
Unrecognized equity return (2)	(242		)	(242		)	—			(287		)	(287		)	—
Unamortized loss on reacquired debt	72			72			—			75			75			—
Pension and postretirement-related regulatory asset (3)	623			32			18			646			31			20
Hurricane Harvey restoration costs (4)	63			56			7			64			58			6
Regulatory assets related to TCJA (5)	48			33			15			48			33			15
Other long-term regulatory assets (6)	210			77			133			211			70			140
Total non-current regulatory assets	2,067			1,321			173			2,347			1,570			181
Total regulatory assets	2,122			1,321			228			2,477			1,570			311
Regulatory Liabilities:
Current regulatory liabilities (7)	43			6			37			24			22			2
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (5)	1,389			885			504			1,354			862			492
Estimated removal costs	885			279			606			878			285			593
Other long-term regulatory liabilities	247			101			146			232			116			116
Total non-current regulatory liabilities	2,521			1,265			1,256			2,464			1,263			1,201
Total regulatory liabilities	2,564			1,271			1,293			2,488			1,285			1,203
Total regulatory assets and liabilities, net	$	(442	)	$	50		$	(1,065	)	$	(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 June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $24 million and $10 million, respectively, of the allowed equity return. During the six months ended June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $45 million and $17 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 $5 million and $7 million as of June 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 June 30, 2018 and December 31, 2017.

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

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(7) Derivative Instruments

The Registrants are exposed to various market risks. These risks arise from transactions entered into in the normal course of business.  The Registrants utilize derivative instruments such as 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

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 activity:

				Three Months Ended June 30,				Six Months Ended June 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.

Hedging of Interest Expense for Future Debt Issuances. In January and February 2018, Houston Electric entered into forward interest rate agreements with multiple counterparties, having an aggregate notional amount of $200 million. These agreements were executed to hedge, in part, volatility in the 30-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows related to interest payments of Houston Electric’s $400 million issuance of fixed rate debt in February 2018. These

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forward interest rate agreements were designated as cash flow hedges. Accordingly, the effective portion of realized gains associated with the forward interest rate agreements, which totaled approximately $5 million, is a component of accumulated other comprehensive income in 2018 and will be amortized over the life of the fixed rate debt.

In March 2018, CERC Corp. entered into forward interest rate agreements with multiple counterparties, having an aggregate notional amount of $450 million. These agreements were executed to hedge, in part, volatility in the 5-year and 10-year U.S. treasury rates by reducing CERC Corp.’s exposure to variability in cash flows related to interest payments of CERC Corp.’s $600 million issuance of fixed rate debt in March 2018. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the effective portion of realized losses associated with the forward interest rate agreements, which totaled less than $1 million, is a component of accumulated other comprehensive income in 2018 and will be amortized over the life of the fixed rate debt.

(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 (CenterPoint Energy and CERC)

		June 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 fair value hedges:		(in millions)
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	$	—	$	3	$	13	$	1
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	76		2		114		4
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	46		—		44		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	23		64		38		78
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	15		41		9		24
Total CERC		160		110		218		107
Indexed debt securities derivative	Current Liabilities	—		641		—		668
Total CenterPoint Energy		$	160	$	751	$	218	$	775

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,862 Bcf or a net 268 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of June 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 $82 million asset and a $130 million asset as of June 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 table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $32 million and $19 million, respectively.

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

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

	June 30, 2018									December 31, 2017
	Gross AmountsRecognized (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	$	99		$	(25	)	$	74		$	165		$	(55	)	$	110
Other Assets: Non-trading derivative assets	61			(15		)	46			53			(9		)	44
Current Liabilities: Non-trading derivative liabilities	(69		)	43			(26		)	(83		)	63			(20		)
Other Liabilities: Non-trading derivative liabilities	(41		)	29			(12		)	(24		)	20			(4		)
Total	$	50		$	32		$	82		$	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.

Realized and unrealized gains and losses on natural gas derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for physical sales derivative contracts and as natural gas expense for financial natural gas derivatives and physical purchase natural gas derivatives. Realized and unrealized gains and losses on indexed debt securities are recorded as Other Income (Expense) in the Condensed Statements of Consolidated Income.

Hedge ineffectiveness is recorded as a component of natural gas expense and primarily results from differences in the location of the derivative instrument and the hedged item. Basis ineffectiveness arises from natural gas market price differences between the locations of the hedged inventory and the delivery location specified in the hedge instruments. The impact of natural gas derivatives designated as fair value hedges, the related hedged item, and natural gas derivatives not designated as hedging instruments are presented in the table below.

Income Statement Impact of Derivative Activity (CenterPoint Energy and CERC)

		Three Months Ended June 30,						Six Months Ended  June 30,
	Income Statement Location	2018			2017			2018			2017
Derivatives designated as fair value hedges:		(in millions)
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	$	13		$	3		$	13		$	12
Natural gas inventory	Gains (Losses) in Non-utility natural gas expense	(12		)	(4		)	(14		)	(14		)
Total CenterPoint Energy and CERC (1)		$	1		$	(1	)	$	(1	)	$	(2	)
Derivatives not designated as hedging instruments:
Natural gas derivatives	Gains (Losses) in Non-utility revenues	$	11		$	36		$	68		$	132
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	(9		)	(9		)	(78		)	(82		)
Total CERC		2			27			(10		)	50
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(254		)	(13		)	(272		)	(23		)
Total CenterPoint Energy		$	(252	)	$	14		$	(282	)	$	27

(1) Hedge ineffectiveness results from the basis ineffectiveness discussed above, and excludes the impact to natural gas expense from timing ineffectiveness.  Timing ineffectiveness arises due to changes in the 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.  As the commodity contract nears the settlement date, spot-to-forward price differences should converge, which should reduce or eliminate the impact of this ineffectiveness on natural gas expense.

(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. 

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CenterPoint Energy and CERC

	June 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

(8) Fair Value Measurements

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

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

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 June 30, 2018, CenterPoint Energy’s and CERC’s Level 3 assets and liabilities are comprised of physical natural gas forward contracts and options and CenterPoint Energy’s indexed debt securities. Level 3 physical natural gas forward contracts and options are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.04 to $3.31 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) and their fair value is sensitive to forward prices. If forward prices decrease, CenterPoint Energy’s and CERC’s long forwards and options lose value whereas their short forwards and options gain in value. CenterPoint Energy’s Level 3 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 unobservable inputs. An increase and a decrease in the unobservable inputs will generally decrease and increase the value of the indexed debt securities derivative, respectively.

The Registrants determine the appropriate level for each financial asset and liability on a quarterly basis and recognize transfers between levels at the end of the reporting period.  For the six months ended June 30, 2018, there were no transfers between Level 1 and 2. The Registrants also recognize purchases of Level 3 financial assets and liabilities at their fair market value at the end of the reporting period.

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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

	June 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	$	586	$	—	$	—	$	—		$	586	$	963	$	—	$	—	$	—		$	963
Investments, including money market funds (2)	70		—		—		—			70		68		—		—		—			68
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	656	$	142	$	18	$	(40	)	$	776	$	1,045	$	161	$	57	$	(64	)	$	1,199
Liabilities
Indexed debt securities derivative	$	—	$	—	$	641	$	—		$	641	$	—	$	—	$	668	$	—		$	668
Natural gas derivatives (3)	—		105		5		(72		)	38		—		96		11		(83		)	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	646	$	(72	)	$	680	$	—	$	96	$	679	$	(83	)	$	692

Houston Electric

	June 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
Total assets	$	52	$	—	$	—	$	—	$	52	$	51	$	—	$	—	$	—	$	51

CERC

	June 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	$	2	$	—	$	—	$	—		$	2	$	3	$	—	$	—	$	—		$	3
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	13	$	142	$	18	$	(40	)	$	133	$	28	$	161	$	57	$	(64	)	$	182
Liabilities
Natural gas derivatives (3)	$	—	$	105	$	5	$	(72	)	$	38	$	—	$	96	$	11	$	(83	)	$	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	5	$	(72	)	$	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 $32 million and $19 million as of June 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.

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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 June 30,												Six Months Ended June 30,
	2018						2017						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	(662	)	$	12		$	(700	)	$	27		$	(622	)	$	46		$	(704	)	$	13
Total gains (losses)	(11		)	1			(6		)	7			(16		)	3			—			23
Total settlements	44			(1		)	—			—			11			(35		)	(4		)	(4		)
Transfers into Level 3	1			1			1			1			1			1			2			2
Transfers out of Level 3	—			—			(7		)	(7		)	(2		)	(2		)	(6		)	(6		)
Ending balance (1)	$	(628	)	$	13		$	(712	)	$	28		$	(628	)	$	13		$	(712	)	$	28
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:
	$	(9	)	$	3		$	(9	)	$	4		$	(23	)	$	(4	)	$	(2	)	$	21

(1) CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during either of the three or six months ended June 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.

	June 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	$	8,256	$	4,919	$	2,722	$	8,679	$	4,753	$	2,457
Fair value	8,470		4,991		2,876		9,220		5,034		2,708

(1) Includes Securitization Bond debt.

(9) Unconsolidated Affiliate (CenterPoint Energy and CERC)

CenterPoint Energy and CERC have 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 for in-substance real estate. Upon the adoption of ASU 2014-09 and ASU 2017-05 on January 1, 2018, CenterPoint Energy and CERC 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 and CERC’s maximum exposure to loss related to Enable, a VIE in which CenterPoint Energy and CERC are not the primary beneficiaries, is limited to the equity investment, the Series A Preferred Unit investment and outstanding current accounts receivable from Enable.

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Limited Partner Interest and Units Held in Enable:

	June 30, 2018
	Limited Partner Interest (1)		Common Units	Series A Preferred Units (2)
CERC Corp.	54.0	%	233,856,623	—
OGE	25.6	%	110,982,805	—
Public unitholders	20.4	%	88,225,208	—
CenterPoint Energy	—		—	14,520,000
Total units outstanding	100.0	%	433,064,636	14,520,000

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

(2) The carrying amount of the Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both June 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.

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 CERC Corp. 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.

Enable is controlled jointly by CERC Corp. and OGE, and each own 50% of the management rights in the general partner of Enable. Sale of CERC Corp.’s or OGE’s ownership interests in Enable’s general partner to a third party is subject to mutual rights of first offer and first refusal, and CERC Corp. is not permitted to dispose of less than all of its interest in Enable’s general partner.

Distributions Received from Enable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Investment in Enable common units	$	75	$	75	$	149	$	149
Total CERC	75		75		149		149
Investment in Enable Series A Preferred Units	9		9		18		18
Total CenterPoint Energy	$	84	$	84	$	167	$	167

As of June 30, 2018, CERC Corp. and OGE also owned 40% and 60%, respectively, of the incentive distribution rights held by the general partner of Enable. 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 its general partner 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, the general partner will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances the general partner of Enable 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.

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Transactions with Enable (CenterPoint Energy and CERC):

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Reimbursement of transition services (1)	$	1	$	1	$	3	$	3
Natural gas expenses, including transportation and storage costs	29		24		66		57

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

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

Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Operating revenues	$	805	$	626	$	1,553	$	1,292
Cost of sales, excluding depreciation and amortization	444		279		819		587
Operating income	126		122		265		262
Net income attributable to Enable	86		86		191		197
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s and CERC’s interest	$	46	$	47	$	103	$	107
Basis difference amortization (1)	12		12		24		24
CenterPoint Energy’s and CERC’s equity in earnings, net	$	58	$	59	$	127	$	131

(1) Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s and CERC’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s and CERC’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:

	June 30, 2018			December 31, 2017
	(in millions)
Current assets	$	432		$	416
Non-current assets	11,360			11,177
Current liabilities	1,258			1,279
Non-current liabilities	2,963			2,660
Non-controlling interest	11			12
Preferred equity	362			362
Enable partners’ equity	7,198			7,280
Reconciliation of Investment in Enable:
CenterPoint Energy’s and CERC’s ownership interest in Enable partners’ equity	$	3,887		$	3,935
CenterPoint Energy’s and CERC’s basis difference	(1,436		)	(1,463		)
CenterPoint Energy’s and CERC’s equity method investment in Enable	$	2,451		$	2,472

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

CenterPoint Energy’s and CERC’s goodwill by reportable business segment as of both June 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.

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.

		June 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	$	(25	)	$	61	$	86	$	(21	)	$	65
Covenants not to compete	4	4		(2		)	2		4		(2		)	2
Other	Various	15		(9		)	6		15		(8		)	7
Total		$	105	$	(36	)	$	69	$	105	$	(31	)	$	74

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Amortization expense of intangible assets	$	2	$	1	$	5	$	3

(11) 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
	June 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 June 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.

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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 six months ended June 30, 2018:

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

(1)Cash of approximately $382 million was paid to ZENS note holders in July 2018.

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

	June 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 June 30, 2018, the contingent principal amount of the ZENS was $484 million.

(12) 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, plus a financing charge. These transactions are accounted for as an inventory financing and had an associated principal obligation of $ -0- and $39 million as of June 30, 2018 and December 31, 2017, respectively.

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(b) Long-term Debt

Debt Issuances. During the six months ended June 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.

Credit Facility. In May 2018, CenterPoint Energy entered into an amendment to its revolving credit facility that will 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.

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

				June 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	$	—	—	%	$	—	$	6	$	855	1.88	%
Houston Electric	300			—		4		—		—		—		4		—		—
CERC Corp.	900			—		1		565		2.37	%	—		1		898		1.72	%
Total	$	2,900		$	—	$	11	$	565			$	—	$	11	$	1,753

(1) Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon 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 June 30, 2018 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,700	(3)	1.250%	75%	(4) (5)	52.1%	March 3, 2022
March 3, 2016	Houston Electric	300			1.125%	65%	(5)	50.7%	March 3, 2022
March 3, 2016	CERC Corp.	900			1.250%	65%		37.8%	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 will increase to $3.3 billion upon the satisfaction of certain conditions described above.

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(4) CenterPoint Energy’s financial covenant limit will return to 65% upon the earlier of (i) June 30, 2019 or (ii) 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 June 30, 2018.

Other. As of both June 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.

(13) Income Taxes

The Registrants reported the following effective tax rates:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
CenterPoint Energy	15	%	36	%	27	%	36	%
Houston Electric	21	%	36	%	22	%	36	%
CERC	22	%	35	%	22	%	37	%

CenterPoint Energy’s lower effective tax rate for the three and six months ended June 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, and partially offset by the impact of state tax law changes which resulted in re-measurement of state deferred taxes. The state tax law changes combined with the lower earnings for the period result in the lower than expected effective tax rate for the current quarter and higher than expected six-month effective tax rate.

Houston Electric’s and CERC’s lower effective tax rate for the three and six months ended June 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 Registrants reported no uncertain tax liability as of June 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. For the 2017 and 2018 tax years, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

(14) 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 June 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.

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

	(in millions)
Remaining six months of 2018	$	185
2019	264
2020	168
2021	82
2022	51
2023 and beyond	123

(b) Legal, Environmental and Other Matters

Legal Matters

Gas Market Manipulation Cases.  CenterPoint Energy, Houston Electric or their predecessor, Reliant Energy, and certain of their former subsidiaries have been named as defendants in certain lawsuits described below. 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.  In May 2009, RRI sold its Texas retail business to a subsidiary of NRG and RRI changed its name to RRI Energy, Inc. In December 2010, Mirant Corporation merged with and became a wholly-owned subsidiary of RRI, and RRI changed its name to GenOn. In December 2012, NRG acquired GenOn through a merger in which GenOn became a wholly-owned subsidiary of NRG. None of the sale of the retail business, the merger with Mirant Corporation, or the acquisition of GenOn by NRG alters RRI’s (now GenOn’s) contractual obligations to indemnify CenterPoint Energy and its subsidiaries, including Houston Electric, for certain liabilities, including their indemnification obligations regarding the gas market manipulation litigation.

A large number of lawsuits were 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 have since been released or dismissed from all such cases. CES, a subsidiary of CERC Corp., was a defendant in a case now pending in federal court in Nevada alleging a conspiracy to inflate Wisconsin natural gas prices in 2000–2002. On May 24, 2016, the district court granted CES’s motion for summary judgment, dismissing CES from the case. The plaintiffs have appealed that ruling. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims. In June 2017, GenOn and various affiliates filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In December 2017, GenOn received court approval of a restructuring plan and is 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. If GenOn were unable to meet its indemnity obligations or satisfy a liability that has been assumed in the gas market manipulation litigation, then CenterPoint Energy, Houston Electric or CERC could incur liability and be responsible for satisfying the liability. CenterPoint Energy does not expect the ultimate outcome of the case against CES 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 June 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. 

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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.

(15) Earnings Per Share (CenterPoint Energy)

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018		2017
	(in millions, except share and per share amounts)
Net income (loss)	$	(75	)	$	135	$	90	$	327
Basic weighted average shares outstanding	431,523,000			430,996,000		431,378,000		430,896,000
Plus: Incremental shares from assumed conversions:
Restricted stock (1)	—			2,801,000		3,029,000		2,801,000
Diluted weighted average shares	431,523,000			433,797,000		434,407,000		433,697,000
Basic earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.76
Diluted earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.75

(1)3,029,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the three months ended June 30, 2018 as their inclusion would be anti-dilutive.

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(16) 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.

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	X	X

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 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 June 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	$	854	(1)	$	—		$	181		$	752	(1)	$	—		$	171
Natural Gas Distribution	487			8			7			470			7			42
Energy Services	841			19			15			918			13			16
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	4			—			(16		)	3			—			11
Eliminations	—			(27		)	—			—			(20		)	—
Consolidated	$	2,186		$	—		$	187		$	2,143		$	—		$	240

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	Six Months Ended June 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	$	1,605	(1)	$	—		$	296		$	1,391	(1)	$	—		$	257
Natural Gas Distribution	1,630			18			163			1,377			16			210
Energy Services	2,098			47			(11		)	2,103			24			51
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	8			—			(10		)	7			—			13
Eliminations	—			(65		)	—			—			(40		)	—
Consolidated	$	5,341		$	—		$	438		$	4,878		$	—		$	531

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	169	$	167	$	330	$	319
Affiliates of Vistra Energy Corp.	59		53		113		100

CERC

	Three Months Ended June 30,
	2018							2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Natural Gas Distribution	$	487	$	8		$	7	$	470		$	7		$	42
Energy Services	841		19			15		918			13			16
Midstream Investments (2)	—		—			—		—			—			—
Other Operations	—		—			—		(1		)	—			1
Eliminations	—		(27		)	—		—			(20		)	—
Consolidated	$	1,328	$	—		$	22	$	1,387		$	—		$	59

	Six Months Ended June 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	$	1,630	$	18		$	163		$	1,377	$	16		$	210
Energy Services	2,098		47			(11		)	2,103		24			51
Midstream Investments (2)	—		—			—			—		—			—
Other Operations	—		—			1			—		—			(3		)
Eliminations	—		(65		)	—			—		(40		)	—
Consolidated	$	3,728	$	—		$	153		$	3,480	$	—		$	258

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	58	$	59	$	127	$	131

CenterPoint Energy and CERC

	Total Assets
	June 30, 2018							December 31, 2017
	CenterPoint  Energy				CERC			CenterPoint Energy				CERC
	(in millions)
Electric Transmission & Distribution	$	10,430			$	—		$	10,292			$	—
Natural Gas Distribution	6,501				6,501			6,608				6,608
Energy Services	1,256				1,256			1,521				1,521
Midstream Investments	2,451				2,451			2,472				2,472
Other Operations	2,311			(3)	89			2,497			(3)	70
Eliminations	(841		)		(655		)	(654		)		(559		)
Consolidated	$	22,108			$	9,642		$	22,736			$	10,112

(3) Includes pension and other postemployment-related regulatory assets of $577 million and $600 million, respectively, as of June 30, 2018 and December 31, 2017.

(17) Supplemental Disclosure of Cash Flow Information

The table below provides supplemental disclosure of cash flow information:

	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	167	$	90	$	50	$	182	$	94	$	56
Income taxes, net	88		120		3		11		76		3
Non-cash transactions:
Accounts payable related to capital expenditures	133		75		69		106		75		44

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:

	June 30, 2018				December 31, 2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Cash and cash equivalents	$	328	$	253	$	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	$	366	$	291	$	296	$	274

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

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(18) 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:

	June 30, 2018						December 31, 2017
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	26		$	—		$	(60	)	$	(570	)
Weighted average interest rate	2.00		%	—		%	1.90		%	1.90		%

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

Affiliate related net interest income (expense) was not material for either the three or six months ended June 30, 2018 or 2017.

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 a number of 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 June 30,										Six Months Ended June 30,
	2018					2017					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	47		$	35	$	44		$	32	$	91		$	69	$	86		$	63
Net affiliate service charges (billings)	(3		)	3		(4		)	4		(5		)	5		(5		)	5

Houston Electric and CERC paid dividends on their common shares and stock, respectively, to Utility Holding, LLC as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2018				2017				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Dividends paid	$	31	$	125	$	10	$	140	$	63	$	211	$	42	$	248

(19) Subsequent Events (CenterPoint Energy and CERC)

CenterPoint Energy Dividend Declaration

On July 26, 2018, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of common stock payable on September 13, 2018 to shareholders of record as of the close of business on August 16, 2018.

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Enable Distributions Declarations

On August 1, 2018, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common units for the quarter ended June 30, 2018. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million from Enable in the third quarter of 2018 to be made with respect to CERC Corp.’s investment in common units of Enable for the second quarter of 2018.

On August 1, 2018, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended June 30, 2018. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the third quarter of 2018 to be made with respect to CenterPoint Energy’s investment in Series A Preferred Units of Enable for the second quarter of 2018.

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

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

The following combined discussion and analysis should be read in combination with the Interim Condensed Financial Statements contained in this Form 10-Q and each Registrants’ 2017 Form 10-K. When discussing CenterPoint Energy’s consolidated financial information, it includes the results of Houston Electric and CERC, which, along with CenterPoint Energy, are collectively referred to as the Registrants. Where appropriate, information relating to a specific Registrant has been segregated and labeled as such. In this Form 10-Q, the terms “our,” “we” and “us” are used as abbreviated references to CenterPoint Energy, Inc. together with its consolidated subsidiaries.

RECENT EVENTS

Proposed Merger with Vectren. 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. For more information about the proposed merger with Vectren, see Note 3 to the Interim Condensed Financial Statements.

AT&T Merger. In June 2018, AT&T’s merger with TW closed. For further information regarding the AT&T merger and its impact on the ZENS, see Note 11 to the Interim Condensed Financial Statements.

Regulatory Proceedings. For details related to our pending and completed regulatory proceedings and orders related to the TCJA to date in 2018, see “—Liquidity and Capital Resources —Regulatory Matters” below.

Credit Facility Amendment. In May 2018, CenterPoint Energy entered into an amendment to its revolving credit facility that will increase the aggregate commitments from $1.7 billion to $3.3 billion under certain conditions. For more information about the amendment, see Note 12 to the Interim Condensed Financial Statements.

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CENTERPOINT ENERGY CONSOLIDATED RESULTS OF OPERATIONS

For information regarding factors that may affect the future results of our consolidated operations, please read “Risk Factors” in Item 1A of Part I of CenterPoint Energy’s 2017 Form 10-K and “Risk Factors” in Item 1A of Part II of CenterPoint Energy’s First Quarter 2018 Form 10-Q and this Form 10-Q.

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions, except per share amounts)
Revenues	$	2,186		$	2,143		$	5,341		$	4,878
Expenses	1,999			1,903			4,903			4,347
Operating Income	187			240			438			531
Interest and Other Finance Charges	(91		)	(77		)	(169		)	(155		)
Interest on Securitization Bonds	(14		)	(20		)	(30		)	(40		)
Equity in Earnings of Unconsolidated Affiliate, net	58			59			127			131
Other Income, net	(228		)	9			(242		)	43
Income (Loss) Before Income Taxes	(88		)	211			124			510
Income Tax Expense (Benefit)	(13		)	76			34			183
Net Income (Loss)	$	(75	)	$	135		$	90		$	327
Basic Earnings (Loss) Per Share	$	(0.17	)	$	0.31		$	0.21		$	0.76
Diluted Earnings (Loss) Per Share	$	(0.17	)	$	0.31		$	0.21		$	0.75

Three months ended June 30, 2018 compared to three months ended June 30, 2017

We reported a net loss of $75 million ($(0.17) per diluted share) for the three months ended June 30, 2018 compared to net income of $135 million ($0.31 per diluted share) for the same period in 2017.

The decrease in net income of $210 million was primarily due to the following key factors:

• a $241 million increase in losses on indexed debt securities related to the ZENS included in Other Income, net shown above, resulting from a loss of $242 million from AT&T’s acquisition of TW in June 2018, partially offset by increased gains of $1 million in the underlying value of the indexed debt securities;

• a $53 million decrease in operating income discussed below by segment;

• a $14 million increase in interest expense due to higher outstanding other long-term debt and the amortization of Bridge Facility fees of $7 million;

• a $1 million decrease in equity earnings from our investment in Enable, discussed further in Note 9 to our Interim Condensed Financial Statements; and

• a $1 million decrease in gains on marketable securities included in Other Income, net shown above.

These decreases in net income were partially offset by the following:

• an $89 million decrease in income tax expense due to lower net income and a reduction in the corporate income tax rate resulting from the TCJA, partially offset by re-measurement of state deferred taxes discussed below;

• a $6 million decrease in interest expense related to lower outstanding balances of our Securitization Bonds; and

• a $5 million increase in miscellaneous other non-operating income included in Other Income, net shown above, primarily due to lower non-service cost components of net periodic pension and postretirement costs.

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Six months ended June 30, 2018 compared to six months ended June 30, 2017

We reported net income of $90 million ($0.21 per diluted share) for the six months ended June 30, 2018 compared to net income of $327 million ($0.75 per diluted share) for the six months ended June 30, 2017.

The decrease in net income of $237 million was primarily due to the following key factors:

• a $249 million increase in losses on indexed debt securities related to the ZENS included in Other Income, net shown above, resulting from a loss of $11 million from Meredith’s acquisition of Time in March 2018 and a loss of $242 million from AT&T’s acquisition of TW in June 2018, partially offset by increased gains of $4 million in the underlying value of the indexed debt securities;

• a $93 million decrease in operating income discussed below by segment;

• a $44 million decrease in gains on marketable securities included in Other Income, net shown above;

• a $14 million increase in interest expense due to higher outstanding other long-term debt and the amortization of Bridge Facility fees of $7 million; and

• a $4 million decrease in equity earnings from our investment in Enable, discussed further in Note 9 to our Interim Condensed Financial Statements.

These decreases in net income were partially offset by the following:

• a $149 million decrease in income tax expense due to lower net income and a reduction in the corporate income tax rate resulting from the TCJA, partially offset by re-measurement of state deferred taxes discussed below;

• a $10 million decrease in interest expense related to lower outstanding balances of our Securitization Bonds; and

• an $8 million increase in miscellaneous other non-operating income included in Other Income, net shown above, primarily due to lower non-service cost components of net periodic pension and postretirement costs.

Income Tax Expense

Our effective tax rate reported for the three months ended June 30, 2018 was 15% compared to 36% for the same period in 2017. The effective tax rate reported for the six months ended June 2018 was 27% compared to 36% for the same period in 2017. The lower effective tax rates for the three and six months ended June 30, 2018 were 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, and partially offset by the impact of state tax law changes which resulted in re-measurement of state deferred taxes. The state tax law changes combined with the lower earnings for the period result in the lower than expected effective tax rate for the current quarter and higher than expected six-month effective tax rate. We expect our annual effective tax rate for the fiscal year ending December 31, 2018 to be approximately 23%.

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HOUSTON ELECTRIC’S MANAGEMENT’S NARRATIVE ANALYSIS

OF CONSOLIDATED RESULTS OF OPERATIONS

Houston Electric’s results of operations are affected by seasonal fluctuations in the demand for electricity. Houston Electric’s results of operations are also affected by, among other things, the actions of various governmental authorities having jurisdiction over rates Houston Electric charges, debt service costs, income tax expense, Houston Electric’s ability to collect receivables from REPs and Houston Electric’s ability to recover its regulatory assets. For more information regarding factors that may affect the future results of operations of Houston Electric’s business, please read “Risk Factors” in Item 1A of Part I of Houston Electric’s 2017 Form 10-K.

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions, except throughput and customer data)
Revenues	$	854		$	752		$	1,609		$	1,390
Expenses	673			581			1,309			1,134
Operating income	181			171			300			256
Interest and other finance charges	(36		)	(32		)	(69		)	(65		)
Interest on Securitization Bonds	(14		)	(20		)	(30		)	(40		)
Other income, net	(3		)	(2		)	(6		)	(6		)
Income before income taxes	128			117			195			145
Income tax expense	27			42			42			52
Net income	$	101		$	75		$	153		$	93

Three months ended June 30, 2018 compared to three months ended June 30, 2017

Houston Electric reported net income of $101 million for the three months ended June 30, 2018 compared to net income of $75 million for the same period in 2017.  

Net income increased $26 million due to the following key factors:

• a $16 million increase in TDU operating income as discussed further below in Results of Operations by Business Segment; and

• a $15 million decrease in income tax expense due to a reduction in the corporate income tax rate resulting from the TCJA.

These increases to net income were partially offset by the following:

• a $4 million increase in interest expense due to higher outstanding other long-term debt; and

• a $1 million decrease in miscellaneous other non-operating income included in Other income, net shown above.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

Houston Electric reported net income of $153 million for the six months ended June 30, 2018 compared to net income of $93 million for the six months ended June 30, 2017.  

Net income increased $60 million, primarily due to the following key factors:

• a $54 million increase in TDU operating income resulting from the $49 million increase discussed further below in Results of Operations by Business Segment and increased usage of $5 million, primarily due to a return to more normal weather, which was not offset by the weather hedge loss recorded on CenterPoint Energy; and

• a $10 million decrease in income tax expense due to a reduction in the corporate income tax rate resulting from the TCJA.

These increases to net income were partially offset by a $4 million increase in interest expense due to higher outstanding other long-term debt.

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Income Tax Expense

Houston Electric’s effective tax rate reported for the three months ended June 30, 2018 was 21% compared to 36% for the same period in 2017. The effective tax rate reported for the six months ended June 30, 2018 was 22% compared to 36% for the same period in 2017. The lower effective tax rate for both the three and six months ended June 30, 2018 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.

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

CERC’s results of operations are affected by seasonal fluctuations in the demand for natural gas and price movements of energy commodities as well as natural gas basis differentials. CERC’s results of operations are also affected by, among other things, the actions of various federal, state and local governmental authorities having jurisdiction over rates CERC charges, competition in CERC’s various business operations, the effectiveness of CERC’s risk management activities, debt service costs and income tax expense. For more information regarding factors that may affect the future results of operations for CERC’s business, please read “Risk Factors” in Item 1A of Part I of CERC’s 2017 Form 10-K.

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Revenues	$	1,328		$	1,387		$	3,728		$	3,480
Expenses	1,306			1,328			3,575			3,222
Operating Income	22			59			153			258
Interest and other finance charges	(33		)	(31		)	(62		)	(60		)
Equity in earnings of unconsolidated affiliate, net	58			59			127			131
Other expense, net	(1		)	(4		)	(5		)	(9		)
Income Before Income Taxes	46			83			213			320
Income tax expense	10			29			47			119
Net Income	$	36		$	54		$	166		$	201

Three months ended June 30, 2018 compared to three months ended June 30, 2017

CERC reported net income of $36 million for the three months ended June 30, 2018 compared to net income of $54 million for the same period in 2017.  

The decrease in net income of $18 million was primarily due to the following key factors:

• a $37 million decrease in operating income discussed below by segment in Results of Operations by Business Segment;

• a $2 million increase in interest expense due to higher outstanding long-term debt; and

• a $1 million decrease in equity earnings from our investment in Enable, discussed further in Note 9 to the Interim Condensed Financial Statements.

These decreases were partially offset by the following:

• a $19 million decrease in income tax expense due to lower net income and a reduction in the corporate income tax rate resulting from the TCJA; and

• a $3 million increase in miscellaneous other non-operating income included in Other expense, net shown above.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

CERC reported net income of $166 million for the six months ended June 30, 2018 compared to net income of $201 million for the six months ended June 30, 2017.  

The decrease in net income of $35 million was primarily due to the following key factors:

• a $105 million decrease in operating income discussed below by segment in Results of Operations by Business Segment;

47

• a $4 million decrease in equity earnings from our investment in Enable, discussed further in Note 9 to the Interim Condensed Financial Statements; and

• a $2 million increase in interest expense due to higher outstanding long-term debt.

These decreases were partially offset by the following:

• a $72 million decrease in income tax expense due to lower net income and a reduction in the corporate income tax rate resulting from the TCJA; and

• a $4 million increase in miscellaneous other non-operating income included in Other expense, net shown above.

Income Tax Expense

CERC’s effective tax rate reported for the three months ended June 30, 2018 was 22% compared to 35% for the same period in 2017. CERC’s effective tax rate reported for the six months ended June 30, 2018 was 22% compared to 37% for the same period in 2017. The lower effective tax rates for both the three and six months ended June 30, 2018 were 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.

RESULTS OF OPERATIONS BY BUSINESS SEGMENT

The following table presents operating income (loss) for each business segment.  Included in revenues are intersegment sales, which are accounted for as if the sales were to third parties at current market prices. See Note 16 to the Interim Condensed Financial Statements for details of business segments by Registrant.

	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018			2017
	(in millions)
Electric Transmission & Distribution	$	181		$	171	$	296		$	257
Natural Gas Distribution	7			42		163			210
Energy Services	15			16		(11		)	51
Other Operations	(16		)	11		(10		)	13
Total Consolidated Operating Income	$	187		$	240	$	438		$	531

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Electric Transmission & Distribution

For information regarding factors that may affect the future results of operations of the Electric Transmission & Distribution business segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Our Electric Transmission & Distribution Business” and “— Other Risk Factors Affecting Our Businesses or Our Interests in Enable Midstream Partners, LP” in Item 1A of Part I of CenterPoint Energy’s 2017 Form 10-K.

The following table provides summary data of our Electric Transmission & Distribution business segment:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions, except throughput and customer data)
Revenues:
TDU	$	676	$	653	$	1,274	$	1,215
Bond Companies	178		99		331		176
Total revenues	854		752		1,605		1,391
Expenses:
Operation and maintenance, excluding Bond Companies	349		341		689		681
Depreciation and amortization, excluding Bond Companies	100		103		198		199
Taxes other than income taxes	60		58		121		118
Bond Companies	164		79		301		136
Total expenses	673		581		1,309		1,134
Operating Income	$	181	$	171	$	296	$	257
Operating Income:
TDU	$	167	$	151	$	266	$	217
Bond Companies (1)	14		20		30		40
Total segment operating income	$	181	$	171	$	296	$	257
Throughput (in GWh):
Residential	8,327		7,940		13,932		13,092
Total	23,688		22,750		43,332		41,504
Number of metered customers at end of period:
Residential	2,179,048		2,152,655		2,179,048		2,152,655
Total	2,463,500		2,429,403		2,463,500		2,429,403

(1) Represents the amount necessary to pay interest on the Securitization Bonds.

Three months ended June 30, 2018 compared to three months ended June 30, 2017

Our Electric Transmission & Distribution business segment reported operating income of $181 million for the three months ended June 30, 2018, consisting of $167 million from the TDU and $14 million related to the Bond Companies. For the three months ended June 30, 2017, operating income totaled $171 million, consisting of $151 million from the TDU and $20 million related to the Bond Companies.

TDU operating income increased $16 million, primarily due to the following key factors:

• higher equity return of $14 million, primarily related to the annual true-up of transition charges correcting for under-collections that occurred during the preceding 12 months;

• higher transmission-related revenues of $7 million, exclusive of the TCJA discussed below, and lower transmission costs billed by transmission providers of $7 million;

• rate increases of $12 million related to distribution capital investments;

49

• higher usage of $9 million, primarily due to a return to more normal weather; and

• customer growth of $8 million from the addition of over 34,000 customers.

These increases to operating income were partially offset by the following:

• lower revenues of $12 million due to the recording of a regulatory liability and a corresponding decrease to revenue reflecting the difference in revenues collected under existing customer rates and the revenues that would have been collected had existing rates been set using the lower corporate tax rate from the TCJA;

• increased operation and maintenance expenses of $15 million, primarily due to increased contract services and corporate support services;

• lower revenues of $7 million due to lower transmission rate filings as a result of the TCJA; and

• higher depreciation and amortization expense, primarily because of ongoing additions to plant in service, and other taxes of $6 million.

Lower depreciation and amortization expenses related to AMS of $7 million were offset by a corresponding decrease in related revenues.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

Our Electric Transmission & Distribution business segment reported operating income of $296 million for the six months ended June 30, 2018, consisting of $266 million from the TDU and $30 million related to the Bond Companies. For the six months ended June 30, 2017, operating income totaled $257 million, consisting of $217 million from the TDU and $40 million related to the Bond Companies.

TDU operating income increased $49 million, primarily due to the following key factors:

• higher equity return of $28 million, primarily related to the annual true-up of transition charges correcting for under-collections that occurred during the preceding 12 months;

• higher transmission-related revenues of $15 million, exclusive of the TCJA discussed below, and lower transmission costs billed by transmission providers of $13 million;

• rate increases of $21 million related to distribution capital investments;

• higher usage of $17 million, primarily due to a return to more normal weather; and

• customer growth of $14 million from the addition of over 34,000 customers.

These increases to operating income were partially offset by the following:

• lower revenues of $24 million due to the recording of a regulatory liability and a corresponding decrease to revenue reflecting the difference in revenues collected under existing customer rates and the revenues that would have been collected had existing rates been set using the lower corporate tax rate from the TCJA;

• increased operation and maintenance expenses of $21 million primarily due to an increase in labor and benefits, contract services and corporate support services;

• lower revenues of $7 million due to lower transmission rate filings as a result of the TCJA; and

• higher depreciation and amortization expense, primarily because of ongoing additions to plant in service, and other taxes of $6 million.

Lower depreciation and amortization expenses related to AMS of $4 million were offset by a corresponding decrease in related revenues.

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Natural Gas Distribution

For information regarding factors that may affect the future results of operations of the Natural Gas Distribution business segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Our Natural Gas Distribution and Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or Our Interests in Enable Midstream Partners, LP” in Item 1A of Part I of CenterPoint Energy’s 2017 Form 10-K.

The following table provides summary data of our Natural Gas Distribution business segment:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions, except throughput and customer data)
Revenues	$	495	$	477	$	1,648	$	1,393
Expenses:
Natural gas	185		164		852		625
Operation and maintenance	196		170		409		359
Depreciation and amortization	69		65		137		128
Taxes other than income taxes	38		36		87		71
Total expenses	488		435		1,485		1,183
Operating Income	$	7	$	42	$	163	$	210
Throughput (in Bcf):
Residential	23		19		110		81
Commercial and industrial	61		57		155		139
Total Throughput	84		76		265		220
Number of customers at end of period:
Residential	3,204,897		3,176,953		3,204,897		3,176,953
Commercial and industrial	255,115		253,559		255,115		253,559
Total	3,460,012		3,430,512		3,460,012		3,430,512

Three months ended June 30, 2018 compared to three months ended June 30, 2017

Our Natural Gas Distribution business segment reported operating income of $7 million for the three months ended June 30, 2018 compared to $42 million for the three months ended June 30, 2017.

Operating income decreased $35 million as a result of the following key factors:

• lower revenues of $16 million due to the timing of a decoupling normalization accrual recorded in the second quarter of 2017 primarily for the impact of weather not recovered by weather normalization adjustments during the 2016-2017 winter season;

• higher labor and benefits costs of $17 million, resulting primarily from the recording of a regulatory asset (and a corresponding reduction in expense) to recover $16 million of prior postretirement expenses in future rates established in the Texas Gulf rate order in 2017;

• higher operation and maintenance expenses of $5 million, primarily due to higher support services expense and bad debt expense of $11 million, partially offset by a timing-related adjustment associated with the Texas Gulf rate order of $6 million;

• lower revenue of $5 million, associated with the recording of a regulatory liability and a corresponding decrease to revenue in certain jurisdictions of $5 million reflecting the difference in revenues collected under existing customer rates and the revenues that would have been collected had existing rates been set using the lower corporate tax rate from the TCJA; and

• increased depreciation and amortization expense of $4 million, primarily due to ongoing additions to plant-in-service.

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These decreases were partially offset by the following:

• rate increases of $7 million, primarily in the Texas and Minnesota jurisdictions, exclusive of the TCJA impact discussed above; and

• a $2 million increase associated with customer growth from the addition of over 29,000 customers.

Increased operation and maintenance expenses related to energy efficiency programs of $4 million and increased gross receipts taxes of $2 million were offset by corresponding increases in the related revenues.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

Our Natural Gas Distribution business segment reported operating income of $163 million for the six months ended June 30, 2018 compared to $210 million for the six months ended June 30, 2017.

Operating income decreased $47 million as a result of the following key factors:

• higher labor and benefits costs of $23 million, resulting primarily from the recording of a regulatory asset (and a corresponding reduction in expense) to recover $16 million of prior postretirement expenses in future rates established in the Texas Gulf rate order in 2017;

• lower revenue of $20 million, associated with the recording of a regulatory liability and a corresponding decrease to revenue in certain jurisdictions of $11 million reflecting the difference in revenues collected under existing customer rates and the revenues that would have been collected had existing rates been set using the lower corporate tax rate from the TCJA and lower rate filings in Minnesota and South Texas of $9 million associated with the lower corporate tax rate as a result of the TCJA;

• higher operation and maintenance expenses of $15 million, primarily due to higher support services expense, contract services expense and bad debt expense of $21 million, partially offset by a timing-related adjustment associated with the Texas Gulf rate order of $6 million;

• lower revenues of $12 million due to the timing of a decoupling normalization accrual recorded in the second quarter of 2017 primarily for the impact of weather not recovered by weather normalization adjustments during the 2016-2017 winter season;

• higher other taxes of $10 million, primarily due to the 2017 Minnesota property tax refund of $9 million; and

• increased depreciation and amortization expense of $8 million, primarily due to ongoing additions to plant-in-service.

These decreases were partially offset by the following:

• rate increases of $29 million, primarily in the Texas, Minnesota and Arkansas jurisdictions, exclusive of the TCJA impact discussed above; and

• a $5 million increase associated with customer growth from the addition of over 29,000 customers.

Increased operation and maintenance expenses related to energy efficiency programs of $12 million and increased gross receipts taxes of $6 million were offset by corresponding increases in the related revenues.

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Energy Services

For information regarding factors that may affect the future results of operations of the Energy Services business segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Our Natural Gas Distribution and Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or Our Interests in Enable Midstream Partners, LP” in Item 1A of Part I of CenterPoint Energy’s 2017 Form 10-K.

The following table provides summary data of our Energy Services business segment:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018			2017
	(in millions, except throughput and customer data)
Revenues	$	860	$	931	$	2,145		$	2,127
Expenses:
Natural gas	820		889		2,101			2,026
Operation and maintenance	21		22		46			43
Depreciation and amortization	3		3		8			6
Taxes other than income taxes	1		1		1			1
Total expenses	845		915		2,156			2,076
Operating Income (Loss)	$	15	$	16	$	(11	)	$	51
Timing impacts related to mark-to-market gain (loss) (1)	$	8	$	6	$	(72	)	$	21
Throughput (in Bcf)	311		273		686			592
Approximate number of customers at end of period (2)	30,000		31,000		30,000			31,000

(1) Includes the change in unrealized mark-to-market value and the impact from derivative assets and liabilities acquired through the purchase of Continuum and AEM.

(2) Does not include approximately 71,000 and 61,000 natural gas customers as of June 30, 2018 and 2017, respectively, that are under residential and small commercial choice programs invoiced by their host utility.

Three months ended June 30, 2018 compared to three months ended June 30, 2017

Our Energy Services business segment reported operating income of $15 million for the three months ended June 30, 2018 compared to $16 million for the three months ended June 30, 2017.

Operating income decreased $1 million, primarily due to timing impacts related to natural gas storage activity. This decrease in operating income was partially offset by decreases to operation and maintenance expenses.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

Our Energy Services business segment reported an operating loss of $11 million for the six months ended June 30, 2018 compared to operating income of $51 million for the six months ended June 30, 2017. 

Operating income decreased $62 million as a result of the following key factors:

• a $93 million decrease from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins;

• a $3 million increase in operation and maintenance expenses, primarily due to higher contract and services expense related to pipeline integrity testing, higher bad debt expense and higher support services expense; and

• a $2 million increase in depreciation and amortization, primarily due to the amortization of AEM acquired intangibles.

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These decreases in operating income were partially offset by a $36 million increase in margin due to incremental volumes from customers and improved margin rates, resulting from realized commercial opportunities attributable to the Continuum and AEM acquisitions and colder than normal weather in several regions of the United States, primarily in the first quarter of 2018.

Midstream Investments

For information regarding factors that may affect the future results of operations of the Midstream Investments business segment, please read “Risk Factors — Risk Factors Affecting Our Interests in Enable Midstream Partners, LP” and “— Other Risk Factors Affecting Our Businesses or Our Interests in Enable Midstream Partners, LP” in Item 1A of Part I of CenterPoint Energy’s 2017 Form 10-K.

The following table provides pre-tax equity income of the Midstream Investments business segment:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Equity earnings from Enable, net	$	58	$	59	$	127	$	131

Other Operations

The following table shows the operating income (loss) of CenterPoint Energy’s Other Operations business segment:

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Revenues	$	4		$	3		$	8		$	7
Expenses	20			(8		)	18			(6		)
Operating Income (Loss)	$	(16	)	$	11		$	(10	)	$	13

Three months ended June 30, 2018 compared to three months ended June 30, 2017

Our Other Operations business segment reported an operating loss of $16 million for the three months ended June 30, 2018 compared to operating income of $11 million for the three months ended June 30, 2017. Operating income decreased $27 million, primarily due to transaction costs related to the Merger.

Six months ended June 30, 2018 compared to six months ended June 30, 2017

Our Other Operations business segment reported an operating loss of $10 million for the three months ended June 30, 2018 compared to operating income of $13 million for the three months ended June 30, 2017. Operating income decreased $23 million, primarily due to transaction costs related to the Merger.

The following table shows the operating income (loss) of CERC’s Other Operations business segment:

	Three Months Ended June 30,					Six Months Ended June 30,
	2018		2017			2018			2017
	(in millions)
Revenues	$	—	$	—		$	—		$	—
Expenses	—		(1		)	(1		)	3
Operating Income (Loss)	$	—	$	1		$	1		$	(3	)

CERTAIN FACTORS AFFECTING FUTURE EARNINGS

For information on other developments, factors and trends that may have an impact on the Registrants’ future earnings, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Certain Factors Affecting Future Earnings” in Item 7 of Part II of CenterPoint Energy’s 2017 Form 10-K, “Risk Factors” in Item 1A of Part I of each of the Registrants’

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2017 Form 10-K and in Item 1A of Part II of CenterPoint Energy’s First Quarter 2018 Form 10-Q and “Cautionary Statement Regarding Forward-Looking Information” in this Form 10-Q.

LIQUIDITY AND CAPITAL RESOURCES

Historical Cash Flows

The following table summarizes the net cash provided by (used in) operating, investing and financing activities:

	Six Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Cash provided by (used in):
Operating activities	$	1,093		$	443		$	746		$	677		$	279		$	278
Investing activities	(267		)	(468		)	(197		)	(640		)	(418		)	(205		)
Financing activities	(756		)	42			(560		)	(138		)	35			(73		)

Operating Activities. The following items contributed to increased (decreased) net cash provided by operating activities for the six months ended June 30, 2018 compared to the same period of 2017:

	CenterPoint Energy			Houston  Electric			CERC
	(in millions)
Changes in net income after adjusting for non-cash items	$	132		$	162		$	(97	)
Changes in working capital	187			10			403
Change in equity in earnings from Enable, net of distributions (1)	122			—			122
Higher pension contribution	(46		)	—			—
Other	21			(8		)	40
	$	416		$	164		$	468

(1) This change is partially offset by the change in distributions from Enable in excess of cumulative earnings in investing activities noted in the table below.

Investing Activities.The following items contributed to (increased) decreased net cash used in investing activities for the six months ended June 30, 2018 compared to the same period of 2017:

	CenterPoint Energy			Houston  Electric			CERC
	(in millions)
Proceeds from the sale of marketable securities	$	398		$	—		$	—
AEM acquisition in 2017	132			—			132
Higher capital expenditures	(48		)	(27		)	(7		)
Net change in notes receivable from unconsolidated affiliates	—			(31		)	—
Change in distributions from Enable in excess of cumulative earnings	(119		)	—			(119		)
Other	10			8			2
	$	373		$	(50	)	$	8

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FinancingActivities. The following items contributed to (increased) decreased net cash used in financing activities for the six months ended June 30, 2018 compared to the same period of 2017:

	CenterPoint Energy			Houston  Electric			CERC
	(in millions)
Net changes in commercial paper outstanding	$	(1,472	)	$	—		$	(482	)
Net changes in long-term debt outstanding, excluding commercial paper	938			89			599
Net changes in debt issuance costs	(29		)	(1		)	(4		)
Net changes in short-term borrowings	(28		)	—			(28		)
Distributions to ZENS note holders	(16		)	—			—
Increased payment of common stock dividends	(10		)	—			—
Net change in notes payable from affiliated companies	—			(60		)	(570		)
Contribution from parent	—			—			(38		)
Dividend to parent	—			(21		)	37
Other	(1		)	—			(1		)
	$	(618	)	$	7		$	(487	)

Future Sources and Uses of Cash

The liquidity and capital requirements of the Registrants, other than in connection with the proposed Merger with Vectren (see Note 3 to the Interim Condensed Financial Statements), are affected primarily by results of operations, capital expenditures, debt service requirements, tax payments, working capital needs and various regulatory actions. Capital expenditures are expected to be used for investment in infrastructure for electric transmission and distribution operations and natural gas distribution operations.  These capital expenditures are anticipated to maintain reliability and safety, increase resiliency and expand our systems through value-added projects. In addition to dividend payments on CenterPoint Energy’s common stock and interest payments on debt, the Registrants’ principal anticipated cash requirements for the remaining six months of 2018 include the following:

	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Estimated capital expenditures	$	972	$	532	$	407
Maturing collateralized pollution control bonds	50		—		—
Scheduled principal payments on Securitization Bonds	204		204		—
Distribution to ZENS note holders	382		—		—

The Registrants expect that anticipated cash needs for the remaining six months of 2018 will be met with borrowings under their credit facilities, proceeds from the issuance of long-term debt, anticipated cash flows from operations and, with respect to CenterPoint Energy and CERC, proceeds from commercial paper and distributions from Enable. In addition, if CenterPoint Energy and CERC decide to sell all or a portion of the Enable common units that they own in the public equity markets or otherwise in 2018 (reducing the amount of future distributions CenterPoint Energy and CERC receives from Enable to the extent of any such sales), any net proceeds received from such sales could provide a source for CenterPoint Energy’s and CERC’s remaining 2018 cash needs. Discretionary financing or refinancing may result in the issuance of equity securities of CenterPoint Energy or debt securities of the Registrants in the capital markets or the arrangement of additional credit facilities or term bank loans. Issuances of equity or debt in the capital markets, funds raised in the commercial paper markets, additional credit facilities and any sales of CenterPoint Energy’s and CERC’s Enable common units may not, however, be available to us on acceptable terms.

For more information on CenterPoint Energy’s acquisition financing plan with respect to the proposed Merger with Vectren, see Note 3 to the Interim Condensed Financial Statements.

Off-Balance Sheet Arrangements

Other than Houston Electric’s first mortgage bonds and general mortgage bonds issued as collateral for tax-exempt long-term debt of CenterPoint Energy as discussed below and operating leases, we have no off-balance sheet arrangements.

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Regulatory Matters

Brazos Valley Connection Project (CenterPoint Energy and Houston Electric)

Houston Electric completed construction on and energized the Brazos Valley Connection in March 2018, ahead of the original June 1, 2018 energization date. The final capital costs of the project were approximately $285 million, which was within the estimated range of approximately $270-$310 million in the PUCT’s original order. Houston Electric applied for interim recovery of project costs not already included in rates in a filing with the PUCT in May 2018 and received approval for interim recovery in July 2018. Final approval by the PUCT of the project costs will occur in Houston Electric’s next base rate case.

Freeport Master Plan Project (CenterPoint Energy and Houston Electric)

In April 2017, Houston Electric submitted a proposal to ERCOT requesting its endorsement of a transmission project in the greater Freeport, Texas area, which includes enhancements to two existing substations and the construction of a new 345 kV double-circuit transmission line located in Brazoria, Matagorda and Wharton counties. On December 12, 2017, Houston Electric received approval from ERCOT. Houston Electric expects to file in September 2018 an application with the PUCT seeking approval to build the project at a current estimated cost of as much as $630 million (previously estimated at $250 million) and anticipates that the PUCT will provide a decision in the third quarter of 2019 regarding the need for and route of the project. The revised preliminary project cost includes additional costs associated with line routing to mitigate environmental and other land use impacts and structure design to address soil and coastal wind conditions.

Rate Change Applications

Houston Electric and CERC are routinely involved in rate change applications before state regulatory authorities.  Those applications include general rate cases, where the entire cost of service of the utility is assessed and reset.  In addition, Houston Electric is periodically involved in proceedings to adjust its capital tracking mechanisms (TCOS and DCRF) and annually files to adjust its EECRF.  CERC is periodically involved in proceedings to adjust its capital tracking mechanisms in Texas (GRIP), its cost of service adjustments in Arkansas, Louisiana, Mississippi and Oklahoma (FRP, RSP, RRA and PBRC, respectively), its decoupling mechanism in Minnesota, and its energy efficiency cost trackers in Arkansas, Minnesota, Mississippi and Oklahoma (EECR, CIP, EECR and EECR, respectively). The table below reflects significant applications pending or completed since our 2017 Form 10-K was filed with the SEC.

Mechanism	Annual Increase (Decrease) (1) (in millions)	Filing  Date	Effective Date	Approval Date	Additional Information
Houston Electric (PUCT)
TCOS	N/A	February 2018	April 2018	April 2018	Revised TCOS annual revenue application approved in November 2017 by a reduction of $41.6 million to recognize decrease in the federal income tax rate, amortize certain EDIT balances and adjust rate base by EDIT attributable to new plant since the last rate case, all of which are related to the TCJA.
TCOS	$40.8	May 2018	July 2018	July 2018	Requested an increase of $285 million to rate base and reflects a $40.8 million annual increase in current revenues. Also reflects a one-time refund of $6.6 million in excess federal income tax collected from January to April 2018.
EECRF	8.4	June 2018	TBD	TBD	Revised application requests recovery of 2019 EECRF of $41.7 million, including a $8.4 million performance bonus.
DCRF	30.9	April 2018	September 2018	TBD	Unanimous settlement agreement results in incremental annual revenue of $30.9 million. The agreement filed with the PUCT in June 2018 recommends a $120.6 million annual revenue requirement effective September 1, 2018. The settlement agreement also reflects an approximately $39 million decrease in the federal income tax rate, a $20 million decrease to return to customers the reserve recorded recognizing this decrease in the federal income tax rate from January 25, 2018 through August 31, 2018 and a $19.2 million decrease related to the unprotected EDIT. Effective September 1, 2019, the reserve amount returned to customers ends.
CERC - South Texas (Railroad Commission)
Rate Case	(1.0)	November 2017	May 2018	May 2018	Unanimous settlement agreement approved by the Railroad Commission in May 2018 that provides for a $1 million annual decrease in current revenues. The settlement agreement also reflects an approximately $2 million decrease in the federal income tax rate and amortization of certain EDIT balances and establishing a 9.8% ROE for future GRIP filings for the South Texas jurisdiction.

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Mechanism	Annual Increase (Decrease) (1) (in millions)	Filing  Date	Effective Date	Approval Date	Additional Information
CERC - Beaumont/East Texas, Houston and Texas Coast (Railroad Commission)
GRIP	14.7	March 2018	July 2018	June 2018	Based on net change in invested capital of $70.0 million and reflects a $14.7 million annual increase in current revenues. Also reflects an approximately $1.0 million decrease in the federal income tax rate.
Administrative 104.111	N/A	July 2018	TBD	TBD	Beaumont/East Texas, Houston and Texas Coast propose to decrease base rates by $12.9 million to reflect the change in the federal income tax rate. In addition, Beaumont/East Texas proposed to decrease the GRIP charge to reflect the change in the federal income tax rate. The impact of deferred taxes is expected to be reflected in the next rate case.
CERC - Arkansas (APSC)
FRP	13.2	August 2018	October 2018	TBD	Based on ROE of 9.5% as approved in the last rate case and reflects a $13.2 million annual increase in current revenues, excluding the effects of the recently enacted TCJA. With TCJA impacts considered, the annual increase is reduced by approximately $8.1 million, which include the effects of a lower federal income tax rate and amortization of EDIT balances.
CERC - Minnesota (MPUC)
Rate Case	56.5	August 2017	TBD	TBD	Reflects a proposed 10.0% ROE on a 52.18% equity ratio. Includes a proposal to extend decoupling beyond current expiration date of June 2018. Interim rates reflecting an annual increase of $47.8 million were effective October 1, 2017. A unanimous settlement agreement was filed in March 2018, which is subject to MPUC approval. The settlement agreement increases base rates by $3.9 million, makes decoupling a permanent part of the tariff, incorporates the impact of the decrease in the federal income tax rate and amortization of EDIT balances (approximately $20 million) and establishes or continues tracker recovery mechanisms that account for approximately $13.3 million in the initial filing. The MPUC voted to approve the settlement and a formal order was issued on July 20, 2018.  Final rates (and the refund of interim rates that exceed final rates) are expected to be implemented later this year after required compliance filings are approved.
CERC - Mississippi (MPSC)
RRA	5.7	May 2018	TBD	TBD	Based on authorized ROE of 9.144% and a capital structure of 50% debt and 50% equity and reflects a $5.7 million annual increase in revenues, excluding the effects of the recently enacted TCJA.  With the impact of the lower federal income tax rate considered, the annual increase is reduced by approximately $1.7 million.
CERC - Oklahoma (OCC)
PBRC	6.7	March 2018	TBD	TBD	Based on ROE of 10% and reflects a $6.7 million annual increase in revenues, excluding the effects of the recently enacted TCJA . With TCJA impacts considered, the annual increase is reduced by approximately $1.2 million, which includes the effects of a lower federal income tax rate and amortization of certain EDIT balances.

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

Tax Reform

For Houston Electric and CERC’s NGD, federal income tax expense is included in the rates approved by state commissions and local municipalities and charged by those utilities to consumers. As Houston Electric and NGD file general rate cases and other periodic rate adjustments, the impacts of the TCJA (including the lower tax rate and the calculation and amortization of EDIT), along with other increases and decreases in our revenue requirements, will be incorporated into Houston Electric’s and NGD’s future rates as allowed by IRS rules. The effect of any potential return of tax savings resulting from the TCJA to consumers may differ depending on how each regulatory body requires us to return such savings. Regulatory commissions across most of Houston Electric’s and NGD’s jurisdictions have issued accounting orders to track or record a regulatory liability for (1) the difference between revenues collected under existing rates and revenues that would have been collected had the existing rates been set using the recently approved federal income tax rates and (2) the balance of EDIT that now exists because of the reduction in federal income tax rates.

On January 25, 2018, the PUCT issued an accounting order in Project No. 47945 directing electric utilities, including Houston Electric, to record as a regulatory liability (1) the difference between revenues collected under existing rates and revenues that would have been collected had the existing rates been set using the recently approved federal income tax rates and (2) the balance of EDIT that now exists because of the reduction in federal income tax rates. On February 13, 2018, Houston Electric and other likely parties to a future rate case announced a settlement that requires Houston Electric to make (i) a TCOS filing by February 20, 2018 to reflect the change in the federal income tax rate for Houston Electric’s transmission rate base through July 31, 2017

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and account for certain EDIT (and such filing was timely submitted), (ii) a DCRF filing in April 2018 to reflect the change in the federal income tax rate for Houston Electric’s distribution rate base through December 31, 2017 (and such filing was timely submitted) and (iii) a full rate case filing by April 30, 2019. The settlement was presented to the PUCT during its open meeting on February 15, 2018. In response to the settlement, the PUCT did not proceed with a prior proposal to require Houston Electric to file a rate case in the summer of 2018. The PUCT also amended its prior accounting order to remove the requirement that utilities include carrying costs in the new regulatory liability. Additional information related to tax reform for Houston Electric is described in the table above.

On January 12, 2018, the APSC issued an order in Docket No. 18-006-U opening an investigatory docket into the TCJA and directing utilities, including CERC, to record as a regulatory liability the current and deferred impacts of the TCJA. On July 26, 2018, the APSC issued an order in the investigatory docket requiring CERC to (1) Include the reduction in tax expense due to the January 1, 2018 change in the tax rate from 35% to 21% in the utility’s FRP as a reduction to the revenue requirement; this reduction will be reflected in the utility’s historical year netting process in the 2019 FRP filing;  (2)  File and include all unprotected EDIT, including plant-related unprotected EDIT, in a separate rider within 30 days and refund the entire balance before December 31, 2019; (3) Include protected EDIT in the FRP and amortize such amount using the ARAM method; and (4) Adjust all other riders impacted by the TCJA changes and apply carrying charges calculated using the pre-tax cost of capital of 6.44% for the amounts related to the TCJA within 30 days of the July 26, 2018 order.

FERC Revised Policy Statement and NOPR (CenterPoint Energy and CERC)

On March 15, 2018, the FERC addressed treatment of federal income tax allowances in FERC-regulated pipeline rates. The FERC issued a Revised Policy Statement stating that it will no longer permit pipelines organized as MLPs to recover an income tax allowance in their cost-of-service rates. The FERC issued the Revised Policy Statement in response to a remand from the U.S. Court of Appeals for the D.C. Circuit in United Airlines v. FERC. On July 18, 2018, the FERC issued an order denying requests for rehearing of its Revised Policy Statement because it is a non-binding policy and parties will have the opportunity to address the policy as applied in future cases. Accordingly, the impacts that such changes may have on the rates Enable can charge for transportation services are unknown at this time.

On March 15, 2018, the FERC also proposed, in a NOPR, the method by which it would apply the Revised Policy Statement to FERC-jurisdictional natural gas pipeline rates, as well as account for the corporate income tax rate reduction in the TCJA. On July 18, 2018, the FERC issued a final rule requiring all FERC-regulated natural gas pipelines that have cost-based rates to make a filing providing certain cost and revenue information and then either propose to reduce or support current cost-based rates, or take no further action. At this time, we cannot predict the outcome of the final rule, but the FERC’s adoption of the regulation could adversely impact the rates Enable is permitted to charge its customers.

Other Matters

Credit Facilities

The Registrants may draw on their respective revolving credit facilities from time to time to provide funds used for general corporate and limited liability company purposes, including to backstop CenterPoint Energy’s and CERC’s commercial paper programs. The facilities may also be utilized to obtain letters of credit. For further details related to the Registrants’ revolving credit facilities, please see Note 12 to the Interim Condensed Financial Statements.

As of July 23, 2018, the Registrants had the following facilities:

Registrant	Size of Facility			Amount Utilized (1)			Termination Date
(in millions)
CenterPoint Energy	$	1,700	(2)	$	309	(3)	March 3, 2022
Houston Electric	300			4		(4)	March 3, 2022
CERC Corp.	900			513		(5)	March 3, 2022

(1) Based on the consolidated debt to capitalization covenant in our revolving credit facility and the revolving credit facility of each of Houston Electric and CERC Corp., we would have been permitted to utilize the full capacity of such revolving credit facilities, which aggregated $2.9 billion as of June 30, 2018.

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(2) Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon the satisfaction of certain conditions. For further information, see Note 12 to the Interim Condensed Financial Statements.

(3) Represents outstanding commercial paper of $303 million and outstanding letters of credit of $6 million.

(4) Represents outstanding letters of credit.

(5) Represents outstanding commercial paper of $512 million and outstanding letters of credit of $1 million.

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

For more information on the Bridge Facility relating to the proposed Merger with Vectren, see Note 3 to the Interim Condensed Financial Statements.

Long-term Debt

In February 2018, Houston Electric issued $400 million aggregate principal amount of general mortgage bonds. In March 2018, CERC Corp. issued $600 million aggregate principal amount of unsecured senior notes. For further information about our 2018 debt issuances, see Note 12 to the Interim Condensed Financial Statements.

As of June 30, 2018, Houston Electric’s outstanding first mortgage bonds and general mortgage bonds aggregated approximately $3.4 billion, of which $118 million is not reflected in its consolidated financial statements because of the contingent nature of the obligation.

The lien of the general mortgage indenture is junior to that of the mortgage pursuant to which the first mortgage bonds are issued. Houston Electric may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee.  Approximately $4.1 billion of additional first mortgage bonds and general mortgage bonds could be issued on the basis of retired bonds and 70% of property additions as of June 30, 2018. Houston Electric has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions.

Houston Electric’s long-term debt consists of its obligations and the obligations of its subsidiaries, including Securitization Bonds issued by its wholly-owned subsidiaries.  As of June 30, 2018, the Bond Companies had the following aggregate principal amount, exclusive of debt issuance costs, of Securitization Bonds outstanding.

Company	Aggregate Principal Amount Outstanding
	(in millions)
Bond Company II	$	296
Bond Company III	110
Bond Company IV	955
Restoration Bond Company	281
Total	$	1,642

The Securitization Bonds are paid through the imposition of “transition” or “system restoration” charges, as defined in the Texas Public Utility Regulatory Act, which are irrevocable, non-bypassable charges to provide recovery of authorized qualified costs. The Securitization Bonds are reported as our long-term debt, although the holders of these bonds have no recourse to any of our assets or revenues, and our creditors have no recourse to any assets or revenues (including, without limitation, the transition or system restoration charges) of the Bond Companies. Houston Electric has no payment obligations with respect to the Securitization Bonds except to remit collections of transition and system restoration charges as set forth in servicing agreements between Houston Electric and the Bond Companies and in an intercreditor agreement among Houston Electric, the Bond Companies and other parties.

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Securities Registered with the SEC

On January 31, 2017, the Registrants filed a joint shelf registration statement with the SEC registering indeterminate principal amounts of Houston Electric’s general mortgage bonds, CERC Corp.’s senior debt securities and CenterPoint Energy’s senior debt securities and junior subordinated debt securities and an indeterminate number of CenterPoint Energy’s shares of common stock, shares of preferred stock, as well as stock purchase contracts and equity units. The joint shelf registration statement will expire on January 31, 2020.

Temporary Investments

As of July 23, 2018, the Registrants had no temporary external investments.

Money Pool (Houston Electric and CERC)

We have a money pool through which the holding company and participating subsidiaries can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the money pool are expected to be met with borrowings under our revolving credit facility or the sale of our commercial paper. The money pool may not provide sufficient funds to meet our subsidiaries’ cash needs. As of July 23, 2018, Houston Electric and CERC had borrowings from the money pool of $63 million and $-0-, respectively.

Impact on Liquidity of a Downgrade in Credit Ratings

The interest on borrowings under the Registrants’ credit facilities is based on their credit ratings. As of July 23, 2018, Moody’s, S&P and Fitch had assigned the following credit ratings to senior debt of the Registrants:

	Moody’s		S&P		Fitch
Company/Instrument	Rating	Outlook (1)	Rating	CreditWatch (2)	Rating	Outlook (3)
CenterPoint Energy Senior Unsecured Debt	Baa1	Negative	BBB+	Negative	BBB	Stable
Houston Electric Senior Secured Debt	A1	Stable	A	Negative	A+	Stable
CERC Corp. Senior Unsecured Debt	Baa2	Stable	A-	Negative	BBB	Positive

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

(2) An S&P CreditWatch assesses the potential direction of a short-term or long-term credit rating.

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

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

A decline in credit ratings could increase borrowing costs under the Registrants’ revolving credit facilities. If the Registrants’ credit ratings had been downgraded one notch by each of the three principal credit rating agencies from the ratings that existed as of June 30, 2018, the impact on the borrowing costs under the three revolving credit facilities would have been immaterial. A decline in credit ratings would also increase the interest rate on long-term debt to be issued in the capital markets and could negatively impact the Registrants’ ability to complete capital market transactions and to access the commercial paper market. Additionally, a decline in credit ratings could increase cash collateral requirements and reduce earnings of CenterPoint Energy’s and CERC’s Natural Gas Distribution and Energy Services business segments.

CES, a wholly-owned subsidiary of CERC Corp. operating in our Energy Services business segment, provides natural gas sales and services primarily to commercial and industrial customers and electric and natural gas utilities throughout the United States. To economically hedge its exposure to natural gas prices, CES uses derivatives with provisions standard for the industry, including those pertaining to credit thresholds. Typically, the credit threshold negotiated with each counterparty defines the amount of unsecured credit that such counterparty will extend to CES. To the extent that the credit exposure that a counterparty has to CES at a particular time does not exceed that credit threshold, CES is not obligated to provide collateral. Mark-to-market exposure

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in excess of the credit threshold is routinely collateralized by CES. Similarly, mark-to-market exposure offsetting and exceeding the credit threshold may cause the counterparty to provide collateral to CES. As of June 30, 2018, the amount posted by CES as collateral aggregated approximately $50 million. Should the credit ratings of CERC Corp. (as the credit support provider for CES) fall below certain levels, CES would be required to provide additional collateral up to the amount of its previously unsecured credit limit. We estimate that as of June 30, 2018, unsecured credit limits extended to CES by counterparties aggregated $348 million, and less than $1 million of such amount was utilized.

Pipeline tariffs and contracts typically provide that if the credit ratings of a shipper or the shipper’s guarantor drop below a threshold level, which is generally investment grade ratings from both Moody’s and S&P, cash or other collateral may be demanded from the shipper in an amount equal to the sum of three months’ charges for pipeline services plus the unrecouped cost of any lateral built for such shipper. If the credit ratings of CERC Corp. decline below the applicable threshold levels, CERC Corp. might need to provide cash or other collateral of as much as $184 million as of June 30, 2018. The amount of collateral will depend on seasonal variations in transportation levels.

ZENS and Securities Related to ZENS (CenterPoint Energy)

If our creditworthiness were to drop such that ZENS holders thought our liquidity was adversely affected or the market for the ZENS were to become illiquid, some ZENS holders might decide to exchange their ZENS for cash. Funds for the payment of cash upon exchange could be obtained from the sale of the shares of ZENS-Related Securities that we own or from other sources. We own shares of ZENS-Related Securities equal to approximately 100% of the reference shares used to calculate our obligation to the holders of the ZENS. ZENS exchanges result in a cash outflow because tax deferrals related to the ZENS and ZENS-Related Securities shares would typically cease when ZENS are exchanged or otherwise retired and ZENS-Related Securities shares are sold. The ultimate tax liability related to the ZENS continues to increase by the amount of the tax benefit realized each year, and there could be a significant cash outflow when the taxes are paid as a result of the retirement of the ZENS. If all ZENS had been exchanged for cash on June 30, 2018, deferred taxes of approximately $408 million would have been payable in 2018. If all the ZENS-Related Securities had been sold on June 30, 2018, capital gains taxes of approximately $100 million would have been payable in 2018.

For additional information about ZENS, see Note 11 to the Interim Condensed Financial Statements.

Cross Defaults

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

Possible Acquisitions, Divestitures and Joint Ventures

From time to time, we consider the acquisition or the disposition of assets or businesses or possible joint ventures, strategic initiatives or other joint ownership arrangements with respect to assets or businesses. Any determination to take action in this regard will be based on market conditions and opportunities existing at the time, and accordingly, the timing, size or success of any efforts and the associated potential capital commitments are unpredictable. We may seek to fund all or part of any such efforts with proceeds from debt and/or equity issuances. Debt or equity financing may not, however, be available to us at that time due to a variety of events, including, among others, maintenance of our credit ratings, industry conditions, general economic conditions, market conditions and market perceptions.

In February 2016, we announced that we were evaluating strategic alternatives for our investment in Enable, including a sale or spin-off qualifying under Section 355 of the U.S. Internal Revenue Code. We have decided that we will not pursue a spin option at this time. In the fourth quarter of 2017, we announced that late-stage discussions with a third party regarding a transaction involving our investment in Enable had terminated because an agreement on mutually acceptable terms could not be reached. We may reduce our ownership in Enable over time through sales in the public equity markets, or otherwise, of the Enable common units we hold, subject to market conditions. Although a transaction for all our interests in Enable is not viable at this time, we may pursue such a transaction if it is viable in the future. There can be no assurances that we will engage in any specific action or that any sale transaction or any sale of Enable common units in the public equity markets or otherwise will be completed, and we do not intend to disclose further developments unless and until our Board of Directors approves a specific transaction or as otherwise required by applicable law or NYSE regulations. Any sale transaction or sale of common units in the public equity markets or otherwise may involve significant costs and expenses, including, in connection with any public offering, a significant underwriting discount. We may not realize any or all of the anticipated strategic, financial, operational or other benefits from any completed sale or reduction in our investment in Enable.

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Enable Midstream Partners (CenterPoint Energy and CERC)

We receive quarterly cash distributions from Enable on its common units and Series A Preferred Units we own. A reduction in the cash distributions we receive from Enable could significantly impact our liquidity. For additional information about cash distributions from Enable, see Notes 9 and 19 to the Interim Condensed Financial Statements.

Hedging of Interest Expense for Future Debt Issuances

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

Weather Hedge (CenterPoint Energy and CERC)

We have historically entered into partial weather hedges for certain NGD jurisdictions and electric operations’ service territory to mitigate the impact of fluctuations from normal weather. We remain exposed to some weather risk as a result of the partial hedges. For more information about our weather hedges, see Note 7(a) to the Interim Condensed Financial Statements.

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

Houston Electric’s receivables from the distribution of electricity are collected from REPs that supply the electricity Houston Electric distributes to their customers. Before conducting business, a REP must register with the PUCT and must meet certain financial qualifications. Nevertheless, adverse economic conditions, structural problems in the market served by ERCOT or financial difficulties of one or more REPs could impair the ability of these REPs to pay for Houston Electric’s services or could cause them to delay such payments. Houston Electric depends on these REPs to remit payments on a timely basis, and any delay or default in payment by REPs could adversely affect Houston Electric’s cash flows. In the event of a REP’s default, Houston Electric’s tariff provides a number of remedies, including the option for Houston Electric to request that the PUCT suspend or revoke the certification of the REP. Applicable regulatory provisions require that customers be shifted to another REP or a provider of last resort if a REP cannot make timely payments. However, Houston Electric remains at risk for payments related to services provided prior to the shift to the replacement REP or the provider of last resort. If a REP were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event such REP might seek to avoid honoring its obligations and claims might be made against Houston Electric involving payments it had received from such REP. If a REP were to file for bankruptcy, Houston Electric may not be successful in recovering accrued receivables owed by such REP that are unpaid as of the date the REP filed for bankruptcy. However, PUCT regulations authorize utilities, such as Houston Electric, to defer bad debts resulting from defaults by REPs for recovery in future rate cases, subject to a review of reasonableness and necessity.

Other Factors that Could Affect Cash Requirements

In addition to the above factors, our liquidity and capital resources could be affected by:

• cash collateral requirements that could exist in connection with certain contracts, including weather hedging arrangements, and natural gas purchases, natural gas price and natural gas storage activities of the Natural Gas Distribution and Energy Services business segments; 

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

• increased costs related to the acquisition of natural gas; 

• increases in interest expense in connection with debt refinancings and borrowings under credit facilities; 

• various legislative or regulatory actions; 

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

• the ability of GenOn and its subsidiaries, currently the subject of bankruptcy proceedings, to satisfy their obligations in respect of GenOn’s indemnity obligations to us;

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• the ability of REPs, including REP affiliates of NRG and Vistra Energy Corp., formerly known as TCEH Corp., to satisfy their obligations to CenterPoint Energy and Houston Electric;

• slower customer payments and increased write-offs of receivables due to higher natural gas prices or changing economic conditions; 

• the outcome of litigation; 

• contributions to pension and postretirement benefit plans; 

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

• various other risks identified in “Risk Factors” in Item 1A of Part I of each of the Registrants’ 2017 Form 10-K and Item 1A of Part II of CenterPoint Energy’s First Quarter 2018 Form 10-Q.

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

Houston Electric has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions. For information about the total debt to capitalization financial covenants in our revolving credit facilities, see Note 12 to the Interim Condensed Financial Statements.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 2 to the Interim Condensed Financial Statements, incorporated herein by reference, for a discussion of new accounting pronouncements that affect us.

Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk (CenterPoint Energy)

As of June 30, 2018, we had outstanding long-term debt, lease obligations and obligations under our ZENS that subject us to the risk of loss associated with movements in market interest rates.

Our floating rate obligations aggregated $565 million and $1.8 billion as of June 30, 2018 and December 31, 2017, respectively. If the floating interest rates were to increase by 10% from June 30, 2018 rates, our combined interest expense would increase by approximately $1 million annually.

As of June 30, 2018 and December 31, 2017, we had outstanding fixed-rate debt (excluding indexed debt securities) aggregating $7.8 billion and $7.0 billion, respectively, in principal amount and having a fair value of $8.0 billion and $7.5 billion, respectively. Because these instruments are fixed-rate, they do not expose us to the risk of loss in earnings due to changes in market interest rates. However, the fair value of these instruments would increase by approximately $266 million if interest rates were to decline by 10% from levels at June 30, 2018. In general, such an increase in fair value would impact earnings and cash flows only if we were to reacquire all or a portion of these instruments in the open market prior to their maturity.

The ZENS obligation is bifurcated into a debt component and a derivative component. The debt component of $26 million as of June 30, 2018 was a fixed-rate obligation and, therefore, did not expose us to the risk of loss in earnings due to changes in market interest rates. However, the fair value of the debt component would increase by approximately $18 million if interest rates were to decline by 10% from levels at June 30, 2018. Changes in the fair value of the derivative component, a $641 million recorded liability at June 30, 2018, are recorded in our Condensed Statements of Consolidated Income and, therefore, we are exposed to changes in the fair value of the derivative component as a result of changes in the underlying risk-free interest rate. If the risk-free interest rate were to increase by 10% from June 30, 2018 levels, the fair value of the derivative component liability would decrease by approximately $2 million, which would be recorded as an unrealized gain in our Condensed Statements of Consolidated Income.

Equity Market Value Risk (CenterPoint Energy)

We are exposed to equity market value risk through our ownership of 10.2 million shares of AT&T Common and 0.9 million shares of Charter Common, which we hold to facilitate our ability to meet our obligations under the ZENS. Changes in the fair value of the ZENS-Related Securities held by CenterPoint Energy are expected to substantially offset changes in the fair value of the derivative component of the ZENS. A decrease of 10% from the June 30, 2018 aggregate market value of these shares would

64

result in a net loss of approximately less than $1 million, which would be recorded as an unrealized loss in our Condensed Statements of Consolidated Income.

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

We use derivative instruments as economic hedges to offset the commodity price exposure inherent in our businesses. The commodity risk created by these instruments, including the offsetting impact on the market value of natural gas inventory, is described below. We measure this commodity risk using a sensitivity analysis. For purposes of this analysis, we estimate commodity price risk by applying a $0.50 change in the forward NYMEX price to our net open fixed price position (including forward fixed price physical contracts, natural gas inventory and fixed price financial contracts) at the end of each period. As of June 30, 2018, the recorded fair value of our non-trading energy derivatives was a net asset of $50 million (before collateral), all of which is related to our Energy Services business segment. A $0.50 change in the forward NYMEX price would have had a combined impact of $8 million on our non-trading energy derivatives net asset and the market value of natural gas inventory.

Commodity price risk is not limited to changes in forward NYMEX prices. Variation of commodity pricing between the different indices used to mark to market portions of our natural gas inventory (Gas Daily) and the related fair value hedge (NYMEX) can result in volatility to our net income. Over time, any gains or losses on the sale of storage gas inventory would be offset by gains or losses on the fair value hedges.

Item 4. CONTROLS AND PROCEDURES

In accordance with Exchange Act Rules 13a-15 and 15d-15, the Registrants carried out separate evaluations, under the supervision and with the participation of each company’s management, including the principal executive officer and principal financial officer, of the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report. Based on those evaluations, the principal executive officer and principal financial officer, in each case, concluded that the disclosure controls and procedures were effective as of June 30, 2018 to provide assurance that information required to be disclosed in the reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding disclosure.

There has been no change in the Registrants’ internal controls over financial reporting that occurred during the three months ended June 30, 2018 that has materially affected, or is reasonably likely to materially affect, the Registrants’ internal controls over financial reporting.

PART II. OTHER INFORMATION

Item 1. LEGAL PROCEEDINGS

For a description of certain legal and regulatory proceedings, please read Note 14(b) to the Interim Condensed Financial Statements and “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Future Sources and Uses of Cash” and “— Regulatory Matters,” each of which is incorporated herein by reference. See also “Business — Regulation” and “— Environmental Matters” in Item 1 and “Legal Proceedings” in Item 3 of each of the Registrants’ 2017 Form 10-K.

Item 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in each of the Registrants’ 2017 Form 10-K and CenterPoint Energy’s First Quarter 2018 Form 10-Q.

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Item 5. OTHER INFORMATION

Ratio of Earnings to Fixed Charges. The Registrants do not believe that the ratios for these six-month periods are necessarily indicative of the ratios for the 12-month periods due to the seasonal nature of their business. The ratios were calculated pursuant to applicable rules of the SEC.

	Six Months Ended June 30,
	2018			2017
	CenterPoint Energy	Houston Electric	CERC	CenterPoint Energy	Houston Electric	CERC
Ratio of earnings to fixed charges	1.69	2.88	4.64	3.61	2.31	6.35

Item 6. EXHIBITS

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

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

Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
2.1*	Agreement and Plan of Merger, dated as of April 21, 2018, by and among Vectren Corporation, CenterPoint Energy, Inc. and Pacer Merger Sub, Inc.	CenterPoint Energy’s Form 8-K dated April 21, 2018	1-31447	2.1	x
3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2	x
3.2	Restated Certificate of Formation of Houston Electric	Houston Electric’s Form 10-Q for the quarter ended June 30, 2011	1-3187	3.1		x
3.3	Certificate of Incorporation of RERC Corp.	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(a)(1)			x
3.4	Certificate of Merger merging former NorAm Energy Corp. with and into HI Merger, Inc. dated August 6, 1997	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(a)(2)			x
3.5	Certificate of Amendment changing the name to Reliant Energy Resources Corp.	CERC Form 10-K for the year ended December 31, 1998	1-13265	3(a)(3)			x
3.6	Certificate of Amendment changing the name to CenterPoint Energy Resources Corp.	CERC Form 10-Q for the quarter ended June 30, 2003	1-13265	3(a)(4)			x
3.7	Third Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated February 21, 2017	1-31447	3.1	x
3.8	Amended and Restated Limited Liability Company Agreement of Houston Electric	Houston Electric’s Form 10-Q for the quarter ended June 30, 2011	1-3187	3.2		x
3.9	Bylaws of RERC Corp.	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(b)			x
3.10	Statement of Resolutions Deleting Shares Designated Series A Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2011	1-31447	3(c)	x

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Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1	x
4.2	$1,600,000,000 Credit Agreement, dated as of March 3, 2016, among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.1	x
4.3	$300,000,000 Credit Agreement, dated as of March 3, 2016, among Houston Electric, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.2	x	x
4.4	$600,000,000 Credit Agreement, dated as of March 3, 2016, among CERC Corp., as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.3	x		x
4.5	First Amendment to Amended and Restated Credit Agreement, dated as of June 16, 2017, by and among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated June 16, 2017	1-31447	4.1	x
4.6	Second Amendment to Amended and Restated Credit Agreement, dated as of May 25, 2018, by and among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated May 25, 2018	1-31447	4.1	x
4.7	First Amendment to Credit Agreement, dated as of June 16, 2017, among Houston Electric, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated June 16, 2017	1-31447	4.2	x	x
4.8	First Amendment to Credit Agreement, dated as of June 16, 2017, among CERC Corp., as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated June 16, 2017	1-31447	4.3	x		x
10.1	Commitment Letter, dated as of April 21, 2018, by Goldman Sachs Bank USA and Morgan Stanley Senior Funding, Inc. to CenterPoint Energy, Inc.	CenterPoint Energy’s Form 8-K dated April 21, 2018	1-31447	10.1	x
+12.1	Computation of Ratios of Earnings to Fixed Charges				x
+12.2	Computation of Ratios of Earnings to Fixed Charges					x
+12.3	Computation of Ratios of Earnings to Fixed Charges						x
+31.1.1	Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka				x
+31.1.2	Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka					x
+31.1.3	Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka						x
+31.2.1	Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers				x
+31.2.2	Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers					x
+31.2.3	Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers						x
+32.1.1	Section 1350 Certification of Scott M. Prochazka				x
+32.1.2	Section 1350 Certification of Scott M. Prochazka					x
+32.1.3	Section 1350 Certification of Scott M. Prochazka						x
+32.2.1	Section 1350 Certification of William D. Rogers				x
+32.2.2	Section 1350 Certification of William D. Rogers					x
+32.2.3	Section 1350 Certification of William D. Rogers						x
+101.INS	XBRL Instance Document				x	x	x

67

Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
+101.SCH	XBRL Taxonomy Extension Schema Document				x	x	x
+101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document				x	x	x
+101.DEF	XBRL Taxonomy Extension Definition Linkbase Document				x	x	x
+101.LAB	XBRL Taxonomy Extension Labels Linkbase Document				x	x	x
+101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document				x	x	x

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

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SIGNATURES

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

	CENTERPOINT ENERGY, INC.
	CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
	CENTERPOINT ENERGY RESOURCES CORP.
By:	/s/ Kristie L. Colvin
	Kristie L. Colvin
	Senior Vice President and Chief Accounting Officer

Date: August 3, 2018

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EX-12.1

Exhibit 12.1

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES

	Six Months Ended June 30,
	2018			2017
	(in millions, except ratios)
Net income	$	90		$	327
Equity in earnings of unconsolidated affiliates, net of distributions	21			18
Income tax expense	34			183
Capitalized interest	(4		)	(4		)
	141			524
Fixed charges, as defined:
Interest	199			195
Capitalized interest	4			4
Interest component of rentals charged to operating expense	1			2
Total fixed charges	204			201
Earnings, as defined	$	345		$	725
Ratio of earnings to fixed charges	1.69			3.61

EX-12.2

Exhibit 12.2

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

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

COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES

	Six Months Ended June 30,
	2018			2017
	(in millions, except ratios)
Net income	$	153		$	93
Income taxes	42			52
Capitalized interest	(3		)	(3		)
	192			142
Fixed charges, as defined:
Interest	99			105
Capitalized interest	3			3
Interest component of rentals charged to operating expense	—			—
Total fixed charges	102			108
Earnings, as defined	$	294		$	250
Ratio of earnings to fixed charges	2.88			2.31

EX-12.3

Exhibit 12.3

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)

COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES

	Six Months Ended June 30,
	2018			2017
	(in millions, except ratios)
Net income	$	166		$	201
Equity in earnings of unconsolidated affiliates, net of distributions	21			18
Income tax expense	47			119
Capitalized interest	(1		)	(1		)
	233			337
Fixed charges, as defined:
Interest	62			60
Capitalized interest	1			1
Interest component of rentals charged to operating expense	1			2
Total fixed charges	64			63
Earnings, as defined	$	297		$	400
Ratio of earnings to fixed charges	4.64			6.35

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, Scott M. Prochazka, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:   August 3, 2018

/s/ Scott M. Prochazka

Scott M. Prochazka

President and Chief Executive Officer

EX-31.1.2

Exhibit 31.1.2

CERTIFICATIONS

I, Scott M. Prochazka, certify that:

1. I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Houston Electric, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  August 3, 2018

/s/ Scott M. Prochazka

Scott M. Prochazka

Chairman (Principal Executive Officer)

EX-31.1.3

Exhibit 31.1.3

CERTIFICATIONS

I, Scott M. Prochazka, certify that:

1.           I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Resources Corp.;

2.           Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.           Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.           The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.           The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:  August 3, 2018

/s/ Scott M. Prochazka

Scott M. Prochazka

President and Chief Executive Officer

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, William D. Rogers, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:   August 3, 2018

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

EX-31.2.2

Exhibit 31.2.2

CERTIFICATIONS

I, William D. Rogers, certify that:

1.I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Houston Electric, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  August 3, 2018

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

EX-31.2.3

Exhibit 31.2.3

CERTIFICATIONS

I, William D. Rogers, certify that:

1.           I have reviewed this quarterly report on Form 10-Q of CenterPoint Energy Resources Corp.;

2.           Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.           Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.           The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.           The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:  August 3, 2018

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

EX-32.1.1

Exhibit 32.1.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott M. Prochazka, Chief Executive Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Scott M. Prochazka

Scott M. Prochazka

President and Chief Executive Officer

August 3, 2018

EX-32.1.2

Exhibit 32.1.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-Q for the three months ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott M. Prochazka, Chairman (Principal Executive Officer), certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Scott M. Prochazka

Scott M. Prochazka

Chairman (Principal Executive Officer)

August 3, 2018

EX-32.1.3

Exhibit 32.1.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Resources Corp. (the “Company”) on Form 10-Q for the three months ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott M. Prochazka, Chief Executive Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.           The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.           The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Scott M. Prochazka

Scott M. Prochazka

President and Chief Executive Officer

August 3, 2018

EX-32.2.1

Exhibit 32.2.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William D. Rogers, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

August 3, 2018

EX-32.2.2

Exhibit 32.2.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-Q for the three months ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William D. Rogers, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

August 3, 2018

EX-32.2.3

Exhibit 32.2.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of CenterPoint Energy Resources Corp. (the “Company”) on Form 10-Q for the three months ended June 30, 2018 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William D. Rogers, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1.           The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.           The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

August 3, 2018

XML

Document and Entity Information - USD ($)	6 Months Ended
	Jun. 30, 2018	Jul. 23, 2018	Jun. 30, 2017
Entity Information [Line Items]
Entity Registrant Name	CENTERPOINT ENERGY INC.
Entity Central Index Key	0001130310
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		431,553,691
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 11,722,467,012
Houston Electric [Member]
Entity Information [Line Items]
Entity Registrant Name	CENTERPOINT ENERGY HOUSTON ELECTRIC LLC
Entity Central Index Key	0000048732
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		1,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
CERC Corp [Member]
Entity Information [Line Items]
Entity Registrant Name	CENTERPOINT ENERGY RESOURCES CORP
Entity Central Index Key	0001042773
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		1,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes

XML

CONDENSED STATEMENTS OF CONSOLIDATED INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenues:
Utility revenues	$ 1,341	$ 1,222	$ 3,235	$ 2,768
Non-utility revenues	845	921	2,106	2,110
Total	2,186	2,143	5,341	4,878
Expenses:
Utility natural gas	188	150	825	600
Non-utility natural gas	790	882	2,063	2,011
Operation and maintenance	578	518	1,147	1,061
Depreciation and amortization	342	254	656	480
Taxes other than income taxes	101	99	212	195
Total	1,999	1,903	4,903	4,347
Operating Income	187	240	438	531
Other Income (Expense):
Gain on marketable securities	22	23	23	67
Loss on indexed debt securities	(254)	(13)	(272)	(23)
Interest and other finance charges	(91)	(77)	(169)	(155)
Interest on Securitization Bonds	(14)	(20)	(30)	(40)
Equity in earnings of unconsolidated affiliate, net	58	59	127	131
Other, net	4	(1)	7	(1)
Total	(275)	(29)	(314)	(21)
Income (Loss) Before Income Taxes	(88)	211	124	510
Income tax expense (benefit)	(13)	76	34	183
Net Income (Loss)	$ (75)	$ 135	$ 90	$ 327
Basic Earnings (Loss) Per Share	$ (0.17)	$ 0.31	$ 0.21	$ 0.76
Diluted Earnings (Loss) Per Share	(0.17)	0.31	0.21	0.75
Dividends Declared Per Share	$ 0.2775	$ 0.2675	$ 0.2775	$ 0.5350
Weighted Average Shares Outstanding, Basic	431,523,000	430,996,000	431,378,000	430,896,000
Weighted Average Shares Outstanding, Diluted	431,523,000	433,797,000	434,407,000	433,697,000
Houston Electric [Member]
Revenues:
Total	$ 854	$ 752	$ 1,609	$ 1,390
Expenses:
Operation and maintenance	351	343	693	684
Depreciation and amortization	262	180	495	332
Taxes other than income taxes	60	58	121	118
Total	673	581	1,309	1,134
Operating Income	181	171	300	256
Other Income (Expense):
Interest and other finance charges	(36)	(32)	(69)	(65)
Interest on Securitization Bonds	(14)	(20)	(30)	(40)
Other, net	(3)	(2)	(6)	(6)
Total	(53)	(54)	(105)	(111)
Income (Loss) Before Income Taxes	128	117	195	145
Income tax expense (benefit)	27	42	42	52
Net Income (Loss)	101	75	153	93
CERC Corp [Member]
Revenues:
Utility revenues	487	470	1,630	1,377
Non-utility revenues	841	917	2,098	2,103
Total	1,328	1,387	3,728	3,480
Expenses:
Utility natural gas	188	150	825	600
Non-utility natural gas	790	882	2,063	2,011
Operation and maintenance	217	190	455	405
Depreciation and amortization	72	68	145	134
Taxes other than income taxes	39	38	87	72
Total	1,306	1,328	3,575	3,222
Operating Income	22	59	153	258
Other Income (Expense):
Interest and other finance charges	(33)	(31)	(62)	(60)
Equity in earnings of unconsolidated affiliate, net	58	59	127	131
Other, net	(1)	(4)	(5)	(9)
Total	24	24	60	62
Income (Loss) Before Income Taxes	46	83	213	320
Income tax expense (benefit)	10	29	47	119
Net Income (Loss)	$ 36	$ 54	$ 166	$ 201

XML

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net income (loss)	$ (75)	$ 135	$ 90	$ 327
Other comprehensive income:
Adjustment to pension and other postretirement plans (net of tax of $-0-, $1, $1 and $2)	2	1	3	2
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $1 and $-0-)	(1)	0	3	(1)
Total	1	1	6	1
Comprehensive income (loss)	(74)	136	96	328
Houston Electric [Member]
Net income (loss)	101	75	153	93
Other comprehensive income:
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $1 and $-0-)	0	0	4	(1)
Total	0	0	4	(1)
Comprehensive income (loss)	101	75	157	92
CERC Corp [Member]
Net income (loss)	36	54	166	201
Other comprehensive income:
Comprehensive income (loss)	$ 36	$ 54	$ 166	$ 201

XML

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (Parentheticals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Tax benefit (expense) on adjustment related to pension and postretirement plans	$ 0	$ (1)	$ (1)	$ (2)
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	0	0	1	0
Houston Electric [Member]
Tax expense (benefit) on net deferred gain (loss) from cash flow hedges	$ 0	$ 0	$ 1	$ 0

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Current Assets:
Cash and cash equivalents	$ 328	$ 260
Investment in marketable securities	584	960
Accounts receivable, less bad debt reserve	958	1,000
Accrued unbilled revenues	207	427
Natural gas inventory	152	222
Materials and supplies	192	175
Non-trading derivative assets	74	110
Taxes receivable	39	0
Prepaid expenses and other current assets	167	241
Total current assets	2,701	3,395
Property, Plant and Equipment:
Property, plant and equipment	19,585	19,031
Less: accumulated depreciation and amortization	6,188	5,974
Property, plant and equipment, net	13,397	13,057
Other Assets:
Goodwill	867	867
Regulatory assets	2,067	2,347
Non-trading derivative assets	46	44
Investment in unconsolidated affiliate	2,451	2,472
Preferred units – unconsolidated affiliate	363	363
Other	216	191
Total other assets	6,010	6,284
Total Assets	22,108	22,736
Current Liabilities:
Short-term borrowings	0	39
Current portion of VIE Securitization Bonds long-term debt	446	434
Indexed debt, net	26	122
Current portion of other long-term debt	50	50
Indexed debt securities derivative	641	668
Accounts payable	706	963
Taxes accrued	103	181
Interest accrued	118	104
Dividends accrued	0	120
Non-trading derivative liabilities	26	20
Due to ZENS note holders	382	0
Other	344	368
Total current liabilities	2,842	3,069
Other Liabilities:
Deferred income taxes, net	3,168	3,174
Non-trading derivative liabilities	12	4
Benefit obligations	723	785
Regulatory liabilities	2,521	2,464
Other	412	357
Total other liabilities	6,836	6,784
Long-term Debt:
VIE Securitization Bonds, net	1,193	1,434
Other long-term debt, net	6,567	6,761
Total long-term debt, net	7,760	8,195
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized, none issued or outstanding	0	0
Common stock	4	4
Additional paid-in capital	4,215	4,209
Retained earnings	513	543
Accumulated other comprehensive income (loss)	(62)	(68)
Total shareholders’ equity	4,670	4,688
Total Liabilities and Shareholders’ Equity	22,108	22,736
Houston Electric [Member]
Current Assets:
Cash and cash equivalents	253	238
Accounts and notes receivable	389	284
Accounts and notes receivable–affiliated companies	32	7
Accrued unbilled revenues	122	120
Materials and supplies	125	119
Taxes receivable	23	0
Prepaid expenses and other current assets	59	62
Total current assets	1,003	830
Property, Plant and Equipment:
Property, plant and equipment	11,812	11,496
Less: accumulated depreciation and amortization	3,741	3,633
Property, plant and equipment, net	8,071	7,863
Other Assets:
Regulatory assets	1,321	1,570
Other	35	29
Total other assets	1,356	1,599
Total Assets	10,430	10,292
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	446	434
Accounts payable	208	243
Accounts and notes payable–affiliated companies	121	104
Taxes accrued	61	116
Interest accrued	75	65
Other	93	120
Total current liabilities	1,004	1,082
Other Liabilities:
Deferred income taxes, net	1,025	1,059
Benefit obligations	143	146
Regulatory liabilities	1,265	1,263
Other	56	54
Total other liabilities	2,489	2,522
Long-term Debt:
VIE Securitization Bonds, net	1,193	1,434
Other long-term debt, net	3,280	2,885
Total long-term debt, net	4,473	4,319
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	1,697	1,696
Retained earnings	763	673
Accumulated other comprehensive income (loss)	4	0
Total shareholders’ equity	2,464	2,369
Total Liabilities and Shareholders’ Equity	10,430	10,292
CERC Corp [Member]
Current Assets:
Cash and cash equivalents	1	12
Accounts receivable, less bad debt reserve	566	713
Accounts and notes receivable–affiliated companies	15	6
Accrued unbilled revenues	85	307
Natural gas inventory	152	222
Materials and supplies	67	56
Non-trading derivative assets	74	110
Prepaid expenses and other current assets	80	166
Total current assets	1,040	1,592
Property, Plant and Equipment:
Property, plant and equipment	7,104	6,888
Less: accumulated depreciation and amortization	2,136	2,036
Property, plant and equipment, net	4,968	4,852
Other Assets:
Goodwill	867	867
Regulatory assets	173	181
Non-trading derivative assets	46	44
Investment in unconsolidated affiliate	2,451	2,472
Other	97	104
Total other assets	3,634	3,668
Total Assets	9,642	10,112
Current Liabilities:
Short-term borrowings	0	39
Accounts payable	434	669
Accounts and notes payable–affiliated companies	36	611
Taxes accrued	48	75
Interest accrued	38	32
Customer deposits	75	76
Non-trading derivative liabilities	26	20
Other	152	137
Total current liabilities	809	1,659
Other Liabilities:
Deferred income taxes, net	1,330	1,289
Non-trading derivative liabilities	12	4
Benefit obligations	98	97
Regulatory liabilities	1,256	1,201
Other	352	297
Total other liabilities	3,048	2,888
Long-term Debt:
Total long-term debt, net	2,722	2,457
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock	0	0
Additional paid-in capital	2,528	2,528
Retained earnings	529	574
Accumulated other comprehensive income (loss)	6	6
Total shareholders’ equity	3,063	3,108
Total Liabilities and Shareholders’ Equity	$ 9,642	$ 10,112

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Cash and cash equivalents	$ 328	$ 260
Accounts receivable, less bad debt reserve	958	1,000
Bad debt reserve	21	19
Prepaid expenses and other current assets	167	241
Regulatory assets	$ 2,067	$ 2,347
Cumulative preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Cumulative preferred stock authorized (in shares)	20,000,000	20,000,000
Cumulative preferred stock outstanding (in shares)	0	0
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)	431,547,782	431,044,845
Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	$ 253	$ 230
Accounts receivable, less bad debt reserve	112	73
Prepaid expenses and other current assets	37	35
Regulatory assets	1,293	1,590
Houston Electric [Member]
Cash and cash equivalents	253	238
Bad debt reserve	1	1
Prepaid expenses and other current assets	59	62
Regulatory assets	1,321	1,570
Houston Electric [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	253	230
Accounts receivable, less bad debt reserve	112	73
Prepaid expenses and other current assets	37	35
Regulatory assets	1,293	1,590
CERC Corp [Member]
Cash and cash equivalents	1	12
Accounts receivable, less bad debt reserve	566	713
Bad debt reserve	20	18
Prepaid expenses and other current assets	80	166
Regulatory assets	$ 173	$ 181

XML

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOW (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash Flows from Operating Activities:
Net income	$ 90	$ 327
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	656	480
Amortization of deferred financing costs	18	12
Deferred income taxes	(12)	95
Unrealized gain on marketable securities	(23)	(67)
Loss on indexed debt securities	272	23
Write-down of natural gas inventory	1	0
Equity in earnings of unconsolidated affiliate, net of distributions	(9)	(131)
Pension contributions	(64)	(18)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	232	234
Inventory	52	(20)
Taxes receivable	(39)	30
Accounts payable	(246)	(158)
Fuel cost recovery	69	(12)
Non-trading derivatives, net	64	(49)
Margin deposits, net	(9)	(43)
Interest and taxes accrued	(64)	(17)
Net regulatory assets and liabilities	57	(34)
Other current assets	(4)	10
Other current liabilities	(13)	(29)
Other assets	(3)	(1)
Other liabilities	60	27
Other, net	8	18
Net cash provided by operating activities	1,093	677
Cash Flows from Investing Activities:
Capital expenditures	(697)	(649)
Acquisitions, net of cash acquired	0	(132)
Distributions from unconsolidated affiliate in excess of cumulative earnings	30	149
Proceeds from sale of marketable securities	398	0
Other, net	2	(8)
Net cash used in investing activities	(267)	(640)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(39)	(11)
Proceeds from (payments of) commercial paper, net	(1,188)	284
Proceeds from long-term debt, net	997	298
Payments of long-term debt	(230)	(469)
Debt issuance costs	(35)	(6)
Payment of dividends on common stock	(240)	(230)
Distribution to ZENS note holders	(16)	0
Other, net	(5)	(4)
Net cash provided by (used in) financing activities	(756)	(138)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	70	(101)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	296	381
Cash, Cash Equivalents and Restricted Cash at End of Period	366	280
Cash and Cash Equivalents at Beginning of Period	260
Cash and Cash Equivalents at End of Period	328
Houston Electric [Member]
Cash Flows from Operating Activities:
Net income	153	93
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	495	332
Amortization of deferred financing costs	6	6
Deferred income taxes	(38)	23
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	(107)	(63)
Accounts receivable/payable–affiliated companies	78	(35)
Inventory	(6)	(1)
Taxes receivable	(23)	(38)
Accounts payable	(6)	57
Interest and taxes accrued	(45)	(41)
Net regulatory assets and liabilities	(59)	(59)
Other current assets	4	2
Other current liabilities	(11)	(7)
Other assets	2	4
Other liabilities	2	1
Other, net	(2)	5
Net cash provided by operating activities	443	279
Cash Flows from Investing Activities:
Capital expenditures	(441)	(414)
Decrease (increase) in notes receivable–affiliated companies	(26)	5
Other, net	(1)	(9)
Net cash used in investing activities	(468)	(418)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	398	298
Payments of long-term debt	(230)	(219)
Decrease in notes payable–affiliated companies	(60)	0
Dividend to parent	(63)	(42)
Debt issuance costs	(4)	(3)
Other, net	1	1
Net cash provided by (used in) financing activities	42	35
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	17	(104)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	274	381
Cash, Cash Equivalents and Restricted Cash at End of Period	291	277
Cash and Cash Equivalents at Beginning of Period	238
Cash and Cash Equivalents at End of Period	253
CERC Corp [Member]
Cash Flows from Operating Activities:
Net income	166	201
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	145	134
Amortization of deferred financing costs	4	4
Deferred income taxes	41	115
Write-down of natural gas inventory	1	0
Equity in earnings of unconsolidated affiliate, net of distributions	(9)	(131)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	339	295
Accounts receivable/payable–affiliated companies	(14)	(1)
Inventory	58	(18)
Accounts payable	(248)	(203)
Fuel cost recovery	69	(12)
Non-trading derivatives, net	61	(49)
Margin deposits, net	(9)	(43)
Interest and taxes accrued	(21)	(27)
Net regulatory assets and liabilities	92	(1)
Other current assets	7	12
Other current liabilities	8	(14)
Other assets	4	5
Other liabilities	52	10
Other, net	0	1
Net cash provided by operating activities	746	278
Cash Flows from Investing Activities:
Capital expenditures	(230)	(223)
Acquisitions, net of cash acquired	0	(132)
Distributions from unconsolidated affiliate in excess of cumulative earnings	30	149
Other, net	3	1
Net cash used in investing activities	(197)	(205)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(39)	(11)
Proceeds from (payments of) commercial paper, net	(333)	149
Proceeds from long-term debt, net	599	0
Decrease in notes payable–affiliated companies	(570)	0
Dividend to parent	(211)	(248)
Debt issuance costs	(5)	(1)
Contribution from parent	0	38
Other, net	(1)	0
Net cash provided by (used in) financing activities	(560)	(73)
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

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Background and Basis of Presentation

6 Months Ended

Jun. 30, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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. CenterPoint Energy’s operating subsidiaries, Houston Electric and CERC, own and operate electric transmission and distribution and natural gas distribution facilities, supply natural gas to commercial and industrial customers and electric and natural gas utilities and own interests in Enable as described below.

• 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 June 30, 2018, CERC Corp. owned approximately 54.0% of the common units representing limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

As of June 30, 2018, CenterPoint Energy also owned an aggregate of 14,520,000 Series A Preferred Units in Enable.

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

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

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

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

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New Accounting Pronouncements

6 Months Ended

Jun. 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 or CERC’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 Series A Preferred Units in Enable, 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 six months ended June 30, 2018 and 2017, respectively, due to the requirement that cash proceeds from COLI policies be classified as cash inflows from investing activity.
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 six months ended June 30, 2018 and 2017, respectively.

Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
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.

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

	Three Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	15	$	8	$	4	$	17	$	7	$	6
Decrease to other income	15		8		4		17		7		6
	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	29	$	15	$	8	$	34	$	15	$	11
Decrease to other income	29		15		8		34		15		11

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 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.	January 1, 2019 Early adoption is permitted	The Registrants will elect the practical expedient on existing easements provided by ASU 2018-01 and 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 2017-12- Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities	This standard expands an entity’s ability to hedge nonfinancial and financial risk components and reduce complexity in fair value hedges of interest rate risk. The guidance eliminates the requirement to separately measure and report hedge ineffectiveness, eases certain documentation and assessment requirements and updates the presentation and disclosure requirements. Transition method: cumulative-effect adjustment for elimination of the separate measurement of ineffectiveness; prospective for presentation and disclosure	January 1, 2019 Early adoption is permitted	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.
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.

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.

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Proposed Merger with Vectren (CenterPoint Energy)

6 Months Ended

Jun. 30, 2018

Business Combinations [Abstract]

Proposed Merger with Vectren (CenterPoint Energy) [Text Block]

Proposed 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. CenterPoint Energy expects to finance the Merger with a combination of debt, equity-linked and equity issuances and has obtained commitments by lenders for a Bridge Facility to provide flexibility for the timing of the long-term acquisition financing and fund, in part, amounts payable by CenterPoint Energy in connection with the Merger. All outstanding debt held by Vectren and its subsidiaries will be assumed by CenterPoint Energy at the closing of the Merger. As of June 30, 2018, Vectren and its subsidiaries had outstanding $248 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 and pursuant to the HSR Act and (ii) 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 July 16, 2018, Vectren filed its definitive proxy statement, as supplemented, with the SEC for a special meeting of its shareholders to be held on August 28, 2018 in connection with the Merger.

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 and 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.

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Revenue Recognition

6 Months Ended

Jun. 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 June 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	$	860		$	509		$	78		$	2	$	1,449		$	758		$	463		$	116		$	1	$	1,338
Derivatives income	—			—			782			—		782			—			—			815			—		815
Other (3)	(6		)	(14		)	—			2		(18		)	(6		)	14			—			2		10
Eliminations	—			(8		)	(19		)	—		(27		)	—			(7		)	(13		)	—		(20		)
Total revenues	$	854		$	487		$	841		$	4	$	2,186		$	752		$	470		$	918		$	3	$	2,143
	Six Months Ended June 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	$	1,621		$	1,695		$	256		$	3	$	3,575		$	1,402		$	1,388		$	258		$	2	$	3,050
Derivatives income	(4		)	—			1,889			—		1,885			1			—			1,869			—		1,870
Other (3)	(12		)	(47		)	—			5		(54		)	(12		)	5			—			5		(2		)
Eliminations	—			(18		)	(47		)	—		(65		)	—			(16		)	(24		)	—		(40		)
Total revenues	$	1,605		$	1,630		$	2,098		$	8	$	5,341		$	1,391		$	1,377		$	2,103		$	7	$	4,878

Houston Electric

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Revenue from contracts	$	860		$	758		$	1,621		$	1,402
Other (3)	(6		)	(6		)	(12		)	(12		)
	$	854		$	752		$	1,609		$	1,390

CERC

	Three Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	509		$	78		$	—	$	587		$	463		$	116		$	—		$	579
Derivatives income	—			782			—		782			—			815			—			815
Other (3)	(14		)	—			—		(14		)	14			—			(1		)	13
Eliminations	(8		)	(19		)	—		(27		)	(7		)	(13		)	—			(20		)
Total revenues	$	487		$	841		$	—	$	1,328		$	470		$	918		$	(1	)	$	1,387
	Six Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	1,695		$	256		$	—	$	1,951		$	1,388		$	258		$	—		$	1,646
Derivatives income	—			1,889			—		1,889			—			1,869			—			1,869
Other (3)	(47		)	—			—		(47		)	5			—			—			5
Eliminations	(18		)	(47		)	—		(65		)	(16		)	(24		)	—			(40		)
Total revenues	$	1,630		$	2,098		$	—	$	3,728		$	1,377		$	2,103		$	—		$	3,480

(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.

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Employee Benefit Plans

6 Months Ended

Jun. 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 June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Service cost (1)	$	9		$	9		$	18		$	18
Interest cost (2)	19			22			39			44
Expected return on plan assets (2)	(26		)	(24		)	(53		)	(48		)
Amortization of prior service cost (2)	2			3			4			5
Amortization of net loss (2)	11			15			22			29
Net periodic cost	$	15		$	25		$	30		$	48

Postretirement Benefits

	Three Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	4			2			1			4			2			1
Expected return on plan assets (2)	(2		)	(1		)	(1		)	(2		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(2		)	1			(1		)	(1		)	1
Net periodic cost	$	2		$	(1	)	$	1		$	2		$	—		$	2
	Six Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	7			4			2			8			4			2
Expected return on plan assets (2)	(3		)	(2		)	(1		)	(3		)	(2		)	—
Amortization of prior service cost (credit) (2)	(2		)	(3		)	1			(2		)	(2		)	1
Net periodic cost	$	3		$	(1	)	$	2		$	4		$	—		$	3

(1) Included in Operation and maintenance expense in the Registrants’ Condensed Statements of Consolidated Income.

(2) Included in Other, net in the Registrants’ Condensed Statements of Consolidated Income.

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

CenterPoint Energy

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Beginning Balance	$	(65	)	$	(71	)	$	(66	)	$	(72	)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	1			1			1			1
Actuarial losses (1)	1			1			3			3
Tax expense	—			(1		)	(1		)	(2		)
Net current period other comprehensive income	2			1			3			2
Ending Balance	$	(63	)	$	(70	)	$	(63	)	$	(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 June 30, 2018						Six Months Ended June 30, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	2	$	—	$	—	$	64	$	—	$	—
Postretirement benefit plan	3		2		1		7		4		2

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Regulatory Accounting

6 Months Ended

Jun. 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:

	June 30, 2018									December 31, 2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	55		$	—		$	55		$	130		$	—		$	130
Non-current regulatory assets:
Securitized regulatory assets	1,293			1,293			—			1,590			1,590			—
Unrecognized equity return (2)	(242		)	(242		)	—			(287		)	(287		)	—
Unamortized loss on reacquired debt	72			72			—			75			75			—
Pension and postretirement-related regulatory asset (3)	623			32			18			646			31			20
Hurricane Harvey restoration costs (4)	63			56			7			64			58			6
Regulatory assets related to TCJA (5)	48			33			15			48			33			15
Other long-term regulatory assets (6)	210			77			133			211			70			140
Total non-current regulatory assets	2,067			1,321			173			2,347			1,570			181
Total regulatory assets	2,122			1,321			228			2,477			1,570			311
Regulatory Liabilities:
Current regulatory liabilities (7)	43			6			37			24			22			2
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (5)	1,389			885			504			1,354			862			492
Estimated removal costs	885			279			606			878			285			593
Other long-term regulatory liabilities	247			101			146			232			116			116
Total non-current regulatory liabilities	2,521			1,265			1,256			2,464			1,263			1,201
Total regulatory liabilities	2,564			1,271			1,293			2,488			1,285			1,203
Total regulatory assets and liabilities, net	$	(442	)	$	50		$	(1,065	)	$	(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 June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $24 million and $10 million, respectively, of the allowed equity return. During the six months ended June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $45 million and $17 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 $5 million and $7 million as of June 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 June 30, 2018 and December 31, 2017.

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

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Derivative Instruments

6 Months Ended

Jun. 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

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 activity:

				Three Months Ended June 30,				Six Months Ended June 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.

Hedging of Interest Expense for Future Debt Issuances. In January and February 2018, Houston Electric entered into forward interest rate agreements with multiple counterparties, having an aggregate notional amount of $200 million. These agreements were executed to hedge, in part, volatility in the 30-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows related to interest payments of Houston Electric’s $400 million issuance of fixed rate debt in February 2018. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the effective portion of realized gains associated with the forward interest rate agreements, which totaled approximately $5 million, is a component of accumulated other comprehensive income in 2018 and will be amortized over the life of the fixed rate debt.

In March 2018, CERC Corp. entered into forward interest rate agreements with multiple counterparties, having an aggregate notional amount of $450 million. These agreements were executed to hedge, in part, volatility in the 5-year and 10-year U.S. treasury rates by reducing CERC Corp.’s exposure to variability in cash flows related to interest payments of CERC Corp.’s $600 million issuance of fixed rate debt in March 2018. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the effective portion of realized losses associated with the forward interest rate agreements, which totaled less than $1 million, is a component of accumulated other comprehensive income in 2018 and will be amortized over the life of the fixed rate debt.

(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 (CenterPoint Energy and CERC)

		June 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 fair value hedges:		(in millions)
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	$	—	$	3	$	13	$	1
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	76		2		114		4
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	46		—		44		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	23		64		38		78
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	15		41		9		24
Total CERC		160		110		218		107
Indexed debt securities derivative	Current Liabilities	—		641		—		668
Total CenterPoint Energy		$	160	$	751	$	218	$	775

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,862 Bcf or a net 268 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of June 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 $82 million asset and a $130 million asset as of June 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 table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $32 million and $19 million, respectively.

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

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

	June 30, 2018									December 31, 2017
	Gross AmountsRecognized (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	$	99		$	(25	)	$	74		$	165		$	(55	)	$	110
Other Assets: Non-trading derivative assets	61			(15		)	46			53			(9		)	44
Current Liabilities: Non-trading derivative liabilities	(69		)	43			(26		)	(83		)	63			(20		)
Other Liabilities: Non-trading derivative liabilities	(41		)	29			(12		)	(24		)	20			(4		)
Total	$	50		$	32		$	82		$	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.

Realized and unrealized gains and losses on natural gas derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for physical sales derivative contracts and as natural gas expense for financial natural gas derivatives and physical purchase natural gas derivatives. Realized and unrealized gains and losses on indexed debt securities are recorded as Other Income (Expense) in the Condensed Statements of Consolidated Income.

Hedge ineffectiveness is recorded as a component of natural gas expense and primarily results from differences in the location of the derivative instrument and the hedged item. Basis ineffectiveness arises from natural gas market price differences between the locations of the hedged inventory and the delivery location specified in the hedge instruments. The impact of natural gas derivatives designated as fair value hedges, the related hedged item, and natural gas derivatives not designated as hedging instruments are presented in the table below.

Income Statement Impact of Derivative Activity (CenterPoint Energy and CERC)

		Three Months Ended June 30,						Six Months Ended  June 30,
	Income Statement Location	2018			2017			2018			2017
Derivatives designated as fair value hedges:		(in millions)
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	$	13		$	3		$	13		$	12
Natural gas inventory	Gains (Losses) in Non-utility natural gas expense	(12		)	(4		)	(14		)	(14		)
Total CenterPoint Energy and CERC (1)		$	1		$	(1	)	$	(1	)	$	(2	)
Derivatives not designated as hedging instruments:
Natural gas derivatives	Gains (Losses) in Non-utility revenues	$	11		$	36		$	68		$	132
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	(9		)	(9		)	(78		)	(82		)
Total CERC		2			27			(10		)	50
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(254		)	(13		)	(272		)	(23		)
Total CenterPoint Energy		$	(252	)	$	14		$	(282	)	$	27

(1) Hedge ineffectiveness results from the basis ineffectiveness discussed above, and excludes the impact to natural gas expense from timing ineffectiveness.  Timing ineffectiveness arises due to changes in the 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.  As the commodity contract nears the settlement date, spot-to-forward price differences should converge, which should reduce or eliminate the impact of this ineffectiveness on natural gas expense.

(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

	June 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

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Fair Value Measurements

6 Months Ended

Jun. 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 assets or liabilities.

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 June 30, 2018, CenterPoint Energy’s and CERC’s Level 3 assets and liabilities are comprised of physical natural gas forward contracts and options and CenterPoint Energy’s indexed debt securities. Level 3 physical natural gas forward contracts and options are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.04 to $3.31 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) and their fair value is sensitive to forward prices. If forward prices decrease, CenterPoint Energy’s and CERC’s long forwards and options lose value whereas their short forwards and options gain in value. CenterPoint Energy’s Level 3 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 unobservable inputs. An increase and a decrease in the unobservable inputs will generally decrease and increase the value of the indexed debt securities derivative, respectively.

The Registrants determine the appropriate level for each financial asset and liability on a quarterly basis and recognize transfers between levels at the end of the reporting period.  For the six months ended June 30, 2018, there were no transfers between Level 1 and 2. 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

	June 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	$	586	$	—	$	—	$	—		$	586	$	963	$	—	$	—	$	—		$	963
Investments, including money market funds (2)	70		—		—		—			70		68		—		—		—			68
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	656	$	142	$	18	$	(40	)	$	776	$	1,045	$	161	$	57	$	(64	)	$	1,199
Liabilities
Indexed debt securities derivative	$	—	$	—	$	641	$	—		$	641	$	—	$	—	$	668	$	—		$	668
Natural gas derivatives (3)	—		105		5		(72		)	38		—		96		11		(83		)	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	646	$	(72	)	$	680	$	—	$	96	$	679	$	(83	)	$	692

Houston Electric

	June 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
Total assets	$	52	$	—	$	—	$	—	$	52	$	51	$	—	$	—	$	—	$	51

CERC

	June 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	$	2	$	—	$	—	$	—		$	2	$	3	$	—	$	—	$	—		$	3
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	13	$	142	$	18	$	(40	)	$	133	$	28	$	161	$	57	$	(64	)	$	182
Liabilities
Natural gas derivatives (3)	$	—	$	105	$	5	$	(72	)	$	38	$	—	$	96	$	11	$	(83	)	$	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	5	$	(72	)	$	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 $32 million and $19 million as of June 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 June 30,												Six Months Ended June 30,
	2018						2017						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	(662	)	$	12		$	(700	)	$	27		$	(622	)	$	46		$	(704	)	$	13
Total gains (losses)	(11		)	1			(6		)	7			(16		)	3			—			23
Total settlements	44			(1		)	—			—			11			(35		)	(4		)	(4		)
Transfers into Level 3	1			1			1			1			1			1			2			2
Transfers out of Level 3	—			—			(7		)	(7		)	(2		)	(2		)	(6		)	(6		)
Ending balance (1)	$	(628	)	$	13		$	(712	)	$	28		$	(628	)	$	13		$	(712	)	$	28
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:
	$	(9	)	$	3		$	(9	)	$	4		$	(23	)	$	(4	)	$	(2	)	$	21

(1) CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during either of the three or six months ended June 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.

	June 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	$	8,256	$	4,919	$	2,722	$	8,679	$	4,753	$	2,457
Fair value	8,470		4,991		2,876		9,220		5,034		2,708

(1) Includes Securitization Bond debt.

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Unconsolidated Affiliate (CenterPoint Energy and CERC)

6 Months Ended

Jun. 30, 2018

Equity Method Investments and Joint Ventures [Abstract]

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

Unconsolidated Affiliate (CenterPoint Energy and CERC)

CenterPoint Energy and CERC have 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 for in-substance real estate. Upon the adoption of ASU 2014-09 and ASU 2017-05 on January 1, 2018, CenterPoint Energy and CERC 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 and CERC’s maximum exposure to loss related to Enable, a VIE in which CenterPoint Energy and CERC are not the primary beneficiaries, is limited to the equity investment, the Series A Preferred Unit investment and outstanding current accounts receivable from Enable.

Limited Partner Interest and Units Held in Enable:

	June 30, 2018
	Limited Partner Interest (1)		Common Units	Series A Preferred Units (2)
CERC Corp.	54.0	%	233,856,623	—
OGE	25.6	%	110,982,805	—
Public unitholders	20.4	%	88,225,208	—
CenterPoint Energy	—		—	14,520,000
Total units outstanding	100.0	%	433,064,636	14,520,000

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

(2) The carrying amount of the Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both June 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.

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 CERC Corp. 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.

Enable is controlled jointly by CERC Corp. and OGE, and each own 50% of the management rights in the general partner of Enable. Sale of CERC Corp.’s or OGE’s ownership interests in Enable’s general partner to a third party is subject to mutual rights of first offer and first refusal, and CERC Corp. is not permitted to dispose of less than all of its interest in Enable’s general partner.

Distributions Received from Enable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Investment in Enable common units	$	75	$	75	$	149	$	149
Total CERC	75		75		149		149
Investment in Enable Series A Preferred Units	9		9		18		18
Total CenterPoint Energy	$	84	$	84	$	167	$	167

As of June 30, 2018, CERC Corp. and OGE also owned 40% and 60%, respectively, of the incentive distribution rights held by the general partner of Enable. 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 its general partner 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, the general partner will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances the general partner of Enable 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.

Transactions with Enable (CenterPoint Energy and CERC):

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Reimbursement of transition services (1)	$	1	$	1	$	3	$	3
Natural gas expenses, including transportation and storage costs	29		24		66		57

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

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

Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Operating revenues	$	805	$	626	$	1,553	$	1,292
Cost of sales, excluding depreciation and amortization	444		279		819		587
Operating income	126		122		265		262
Net income attributable to Enable	86		86		191		197
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s and CERC’s interest	$	46	$	47	$	103	$	107
Basis difference amortization (1)	12		12		24		24
CenterPoint Energy’s and CERC’s equity in earnings, net	$	58	$	59	$	127	$	131

(1) Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s and CERC’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s and CERC’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:

	June 30, 2018			December 31, 2017
	(in millions)
Current assets	$	432		$	416
Non-current assets	11,360			11,177
Current liabilities	1,258			1,279
Non-current liabilities	2,963			2,660
Non-controlling interest	11			12
Preferred equity	362			362
Enable partners’ equity	7,198			7,280
Reconciliation of Investment in Enable:
CenterPoint Energy’s and CERC’s ownership interest in Enable partners’ equity	$	3,887		$	3,935
CenterPoint Energy’s and CERC’s basis difference	(1,436		)	(1,463		)
CenterPoint Energy’s and CERC’s equity method investment in Enable	$	2,451		$	2,472

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Goodwill and Other Intangibles (CenterPoint Energy and CERC)

6 Months Ended

Jun. 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 June 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.

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.

		June 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	$	(25	)	$	61	$	86	$	(21	)	$	65
Covenants not to compete	4	4		(2		)	2		4		(2		)	2
Other	Various	15		(9		)	6		15		(8		)	7
Total		$	105	$	(36	)	$	69	$	105	$	(31	)	$	74

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Amortization expense of intangible assets	$	2	$	1	$	5	$	3

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

6 Months Ended

Jun. 30, 2018

Investments, Debt and Equity Securities [Abstract]

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

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

(a) Investment in Securities Related to ZENS

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
	June 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 June 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 six months ended June 30, 2018:

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

(1)Cash of approximately $382 million was paid to ZENS note holders in July 2018.

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

	June 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 June 30, 2018, the contingent principal amount of the ZENS was $484 million.

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Short-Term Borrowings and Long-term Debt

6 Months Ended

Jun. 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, plus a financing charge. These transactions are accounted for as an inventory financing and had an associated principal obligation of $ -0- and $39 million as of June 30, 2018 and December 31, 2017, respectively.

(b) Long-term Debt

Debt Issuances. During the six months ended June 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.

Credit Facility. In May 2018, CenterPoint Energy entered into an amendment to its revolving credit facility that will 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.

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

				June 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	$	—	—	%	$	—	$	6	$	855	1.88	%
Houston Electric	300			—		4		—		—		—		4		—		—
CERC Corp.	900			—		1		565		2.37	%	—		1		898		1.72	%
Total	$	2,900		$	—	$	11	$	565			$	—	$	11	$	1,753

(1) Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon 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 June 30, 2018 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,700	(3)	1.250%	75%	(4) (5)	52.1%	March 3, 2022
March 3, 2016	Houston Electric	300			1.125%	65%	(5)	50.7%	March 3, 2022
March 3, 2016	CERC Corp.	900			1.250%	65%		37.8%	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 will increase to $3.3 billion upon the satisfaction of certain conditions described above.

(4) CenterPoint Energy’s financial covenant limit will return to 65% upon the earlier of (i) June 30, 2019 or (ii) 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 June 30, 2018.

Other. As of both June 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.

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Income Taxes

6 Months Ended

Jun. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes [Text Block]

Income Taxes

The Registrants reported the following effective tax rates:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
CenterPoint Energy	15	%	36	%	27	%	36	%
Houston Electric	21	%	36	%	22	%	36	%
CERC	22	%	35	%	22	%	37	%

CenterPoint Energy’s lower effective tax rate for the three and six months ended June 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, and partially offset by the impact of state tax law changes which resulted in re-measurement of state deferred taxes. The state tax law changes combined with the lower earnings for the period result in the lower than expected effective tax rate for the current quarter and higher than expected six-month effective tax rate.

Houston Electric’s and CERC’s lower effective tax rate for the three and six months ended June 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 Registrants reported no uncertain tax liability as of June 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. For the 2017 and 2018 tax years, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

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Commitments and Contingencies

6 Months Ended

Jun. 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 June 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 June 30, 2018, minimum payment obligations for natural gas supply commitments are approximately:

	(in millions)
Remaining six months of 2018	$	185
2019	264
2020	168
2021	82
2022	51
2023 and beyond	123

(b) Legal, Environmental and Other Matters

Legal Matters

Gas Market Manipulation Cases.  CenterPoint Energy, Houston Electric or their predecessor, Reliant Energy, and certain of their former subsidiaries have been named as defendants in certain lawsuits described below. 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.  In May 2009, RRI sold its Texas retail business to a subsidiary of NRG and RRI changed its name to RRI Energy, Inc. In December 2010, Mirant Corporation merged with and became a wholly-owned subsidiary of RRI, and RRI changed its name to GenOn. In December 2012, NRG acquired GenOn through a merger in which GenOn became a wholly-owned subsidiary of NRG. None of the sale of the retail business, the merger with Mirant Corporation, or the acquisition of GenOn by NRG alters RRI’s (now GenOn’s) contractual obligations to indemnify CenterPoint Energy and its subsidiaries, including Houston Electric, for certain liabilities, including their indemnification obligations regarding the gas market manipulation litigation.

A large number of lawsuits were 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 have since been released or dismissed from all such cases. CES, a subsidiary of CERC Corp., was a defendant in a case now pending in federal court in Nevada alleging a conspiracy to inflate Wisconsin natural gas prices in 2000–2002. On May 24, 2016, the district court granted CES’s motion for summary judgment, dismissing CES from the case. The plaintiffs have appealed that ruling. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims. In June 2017, GenOn and various affiliates filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In December 2017, GenOn received court approval of a restructuring plan and is 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. If GenOn were unable to meet its indemnity obligations or satisfy a liability that has been assumed in the gas market manipulation litigation, then CenterPoint Energy, Houston Electric or CERC could incur liability and be responsible for satisfying the liability. CenterPoint Energy does not expect the ultimate outcome of the case against CES 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 June 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.

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Earnings Per Share (CenterPoint Energy)

6 Months Ended

Jun. 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 (loss) per share calculations:

	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018		2017
	(in millions, except share and per share amounts)
Net income (loss)	$	(75	)	$	135	$	90	$	327
Basic weighted average shares outstanding	431,523,000			430,996,000		431,378,000		430,896,000
Plus: Incremental shares from assumed conversions:
Restricted stock (1)	—			2,801,000		3,029,000		2,801,000
Diluted weighted average shares	431,523,000			433,797,000		434,407,000		433,697,000
Basic earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.76
Diluted earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.75

(1)3,029,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the three months ended June 30, 2018 as their inclusion would be anti-dilutive.

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Reportable Business Segments

6 Months Ended

Jun. 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.

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	X	X

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 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 June 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	$	854	(1)	$	—		$	181		$	752	(1)	$	—		$	171
Natural Gas Distribution	487			8			7			470			7			42
Energy Services	841			19			15			918			13			16
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	4			—			(16		)	3			—			11
Eliminations	—			(27		)	—			—			(20		)	—
Consolidated	$	2,186		$	—		$	187		$	2,143		$	—		$	240

	Six Months Ended June 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	$	1,605	(1)	$	—		$	296		$	1,391	(1)	$	—		$	257
Natural Gas Distribution	1,630			18			163			1,377			16			210
Energy Services	2,098			47			(11		)	2,103			24			51
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	8			—			(10		)	7			—			13
Eliminations	—			(65		)	—			—			(40		)	—
Consolidated	$	5,341		$	—		$	438		$	4,878		$	—		$	531

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	169	$	167	$	330	$	319
Affiliates of Vistra Energy Corp.	59		53		113		100

CERC

	Three Months Ended June 30,
	2018							2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Natural Gas Distribution	$	487	$	8		$	7	$	470		$	7		$	42
Energy Services	841		19			15		918			13			16
Midstream Investments (2)	—		—			—		—			—			—
Other Operations	—		—			—		(1		)	—			1
Eliminations	—		(27		)	—		—			(20		)	—
Consolidated	$	1,328	$	—		$	22	$	1,387		$	—		$	59

	Six Months Ended June 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	$	1,630	$	18		$	163		$	1,377	$	16		$	210
Energy Services	2,098		47			(11		)	2,103		24			51
Midstream Investments (2)	—		—			—			—		—			—
Other Operations	—		—			1			—		—			(3		)
Eliminations	—		(65		)	—			—		(40		)	—
Consolidated	$	3,728	$	—		$	153		$	3,480	$	—		$	258

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	58	$	59	$	127	$	131

CenterPoint Energy and CERC

	Total Assets
	June 30, 2018							December 31, 2017
	CenterPoint  Energy				CERC			CenterPoint Energy				CERC
	(in millions)
Electric Transmission & Distribution	$	10,430			$	—		$	10,292			$	—
Natural Gas Distribution	6,501				6,501			6,608				6,608
Energy Services	1,256				1,256			1,521				1,521
Midstream Investments	2,451				2,451			2,472				2,472
Other Operations	2,311			(3)	89			2,497			(3)	70
Eliminations	(841		)		(655		)	(654		)		(559		)
Consolidated	$	22,108			$	9,642		$	22,736			$	10,112

(3) Includes pension and other postemployment-related regulatory assets of $577 million and $600 million, respectively, as of June 30, 2018 and December 31, 2017.

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Supplemental Disclosure of Cash Flow Information

6 Months Ended

Jun. 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:

	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	167	$	90	$	50	$	182	$	94	$	56
Income taxes, net	88		120		3		11		76		3
Non-cash transactions:
Accounts payable related to capital expenditures	133		75		69		106		75		44

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:

	June 30, 2018				December 31, 2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Cash and cash equivalents	$	328	$	253	$	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	$	366	$	291	$	296	$	274

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

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Related Party Transactions (Houston Electric and CERC)

6 Months Ended

Jun. 30, 2018

Related Party Transactions [Abstract]

Related Party Transactions (Houston Electric and CERC) [Text Block]

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:

	June 30, 2018						December 31, 2017
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	26		$	—		$	(60	)	$	(570	)
Weighted average interest rate	2.00		%	—		%	1.90		%	1.90		%

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

Affiliate related net interest income (expense) was not material for either the three or six months ended June 30, 2018 or 2017.

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 a number of 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 June 30,										Six Months Ended June 30,
	2018					2017					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	47		$	35	$	44		$	32	$	91		$	69	$	86		$	63
Net affiliate service charges (billings)	(3		)	3		(4		)	4		(5		)	5		(5		)	5

Houston Electric and CERC paid dividends on their common shares and stock, respectively, to Utility Holding, LLC as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2018				2017				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Dividends paid	$	31	$	125	$	10	$	140	$	63	$	211	$	42	$	248

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Subsequent Events (CenterPoint Energy and CERC)

6 Months Ended

Jun. 30, 2018

Subsequent Events [Abstract]

Subsequent Events (CenterPoint Energy and CERC) [Text Block]

Subsequent Events (CenterPoint Energy and CERC)

CenterPoint Energy Dividend Declaration

On July 26, 2018, CenterPoint Energy’s Board of Directors declared a regular quarterly cash dividend of $0.2775 per share of common stock payable on September 13, 2018 to shareholders of record as of the close of business on August 16, 2018.

Enable Distributions Declarations

On August 1, 2018, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common units for the quarter ended June 30, 2018. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million from Enable in the third quarter of 2018 to be made with respect to CERC Corp.’s investment in common units of Enable for the second quarter of 2018.

On August 1, 2018, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended June 30, 2018. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the third quarter of 2018 to be made with respect to CenterPoint Energy’s investment in Series A Preferred Units of Enable for the second quarter of 2018.

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New Accounting Pronouncements (Tables)

6 Months Ended

Jun. 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 or CERC’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 Series A Preferred Units in Enable, 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 six months ended June 30, 2018 and 2017, respectively, due to the requirement that cash proceeds from COLI policies be classified as cash inflows from investing activity.
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 six months ended June 30, 2018 and 2017, respectively.

Recently Adopted Accounting Standards
ASU Number and Name	Description	Date of Adoption	Financial Statement Impact upon Adoption
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.

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

	Three Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	15	$	8	$	4	$	17	$	7	$	6
Decrease to other income	15		8		4		17		7		6
	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Increase to operating income	$	29	$	15	$	8	$	34	$	15	$	11
Decrease to other income	29		15		8		34		15		11

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 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.	January 1, 2019 Early adoption is permitted	The Registrants will elect the practical expedient on existing easements provided by ASU 2018-01 and 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 2017-12- Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities	This standard expands an entity’s ability to hedge nonfinancial and financial risk components and reduce complexity in fair value hedges of interest rate risk. The guidance eliminates the requirement to separately measure and report hedge ineffectiveness, eases certain documentation and assessment requirements and updates the presentation and disclosure requirements. Transition method: cumulative-effect adjustment for elimination of the separate measurement of ineffectiveness; prospective for presentation and disclosure	January 1, 2019 Early adoption is permitted	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.
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.

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Revenue Recognition (Tables)

6 Months Ended

Jun. 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 June 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	$	860		$	509		$	78		$	2	$	1,449		$	758		$	463		$	116		$	1	$	1,338
Derivatives income	—			—			782			—		782			—			—			815			—		815
Other (3)	(6		)	(14		)	—			2		(18		)	(6		)	14			—			2		10
Eliminations	—			(8		)	(19		)	—		(27		)	—			(7		)	(13		)	—		(20		)
Total revenues	$	854		$	487		$	841		$	4	$	2,186		$	752		$	470		$	918		$	3	$	2,143
	Six Months Ended June 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	$	1,621		$	1,695		$	256		$	3	$	3,575		$	1,402		$	1,388		$	258		$	2	$	3,050
Derivatives income	(4		)	—			1,889			—		1,885			1			—			1,869			—		1,870
Other (3)	(12		)	(47		)	—			5		(54		)	(12		)	5			—			5		(2		)
Eliminations	—			(18		)	(47		)	—		(65		)	—			(16		)	(24		)	—		(40		)
Total revenues	$	1,605		$	1,630		$	2,098		$	8	$	5,341		$	1,391		$	1,377		$	2,103		$	7	$	4,878

Houston Electric

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Revenue from contracts	$	860		$	758		$	1,621		$	1,402
Other (3)	(6		)	(6		)	(12		)	(12		)
	$	854		$	752		$	1,609		$	1,390

CERC

	Three Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	509		$	78		$	—	$	587		$	463		$	116		$	—		$	579
Derivatives income	—			782			—		782			—			815			—			815
Other (3)	(14		)	—			—		(14		)	14			—			(1		)	13
Eliminations	(8		)	(19		)	—		(27		)	(7		)	(13		)	—			(20		)
Total revenues	$	487		$	841		$	—	$	1,328		$	470		$	918		$	(1	)	$	1,387
	Six Months Ended June 30,
	2018											2017
	Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy  Services  (2)			Other Operations (2)			Total
	(in millions)
Revenue from contracts	$	1,695		$	256		$	—	$	1,951		$	1,388		$	258		$	—		$	1,646
Derivatives income	—			1,889			—		1,889			—			1,869			—			1,869
Other (3)	(47		)	—			—		(47		)	5			—			—			5
Eliminations	(18		)	(47		)	—		(65		)	(16		)	(24		)	—			(40		)
Total revenues	$	1,630		$	2,098		$	—	$	3,728		$	1,377		$	2,103		$	—		$	3,480

(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.

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 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 June 30, 2018						Six Months Ended June 30, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Pension plans	$	2	$	—	$	—	$	64	$	—	$	—
Postretirement benefit plan	3		2		1		7		4		2

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 June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Service cost (1)	$	9		$	9		$	18		$	18
Interest cost (2)	19			22			39			44
Expected return on plan assets (2)	(26		)	(24		)	(53		)	(48		)
Amortization of prior service cost (2)	2			3			4			5
Amortization of net loss (2)	11			15			22			29
Net periodic cost	$	15		$	25		$	30		$	48

Postretirement Benefits

	Three Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	4			2			1			4			2			1
Expected return on plan assets (2)	(2		)	(1		)	(1		)	(2		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(2		)	1			(1		)	(1		)	1
Net periodic cost	$	2		$	(1	)	$	1		$	2		$	—		$	2
	Six Months Ended June 30,
	2018									2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)
Service cost (1)	$	1		$	—		$	—		$	1		$	—		$	—
Interest cost (2)	7			4			2			8			4			2
Expected return on plan assets (2)	(3		)	(2		)	(1		)	(3		)	(2		)	—
Amortization of prior service cost (credit) (2)	(2		)	(3		)	1			(2		)	(2		)	1
Net periodic cost	$	3		$	(1	)	$	2		$	4		$	—		$	3

(1) Included in Operation and maintenance expense in the Registrants’ Condensed Statements of Consolidated Income.

(2) Included in Other, net in the Registrants’ Condensed Statements of Consolidated Income.

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 June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(in millions)
Beginning Balance	$	(65	)	$	(71	)	$	(66	)	$	(72	)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	1			1			1			1
Actuarial losses (1)	1			1			3			3
Tax expense	—			(1		)	(1		)	(2		)
Net current period other comprehensive income	2			1			3			2
Ending Balance	$	(63	)	$	(70	)	$	(63	)	$	(70	)

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

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Regulatory Accounting (Tables)

6 Months Ended

Jun. 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:

	June 30, 2018									December 31, 2017
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)
Current regulatory assets (1)	$	55		$	—		$	55		$	130		$	—		$	130
Non-current regulatory assets:
Securitized regulatory assets	1,293			1,293			—			1,590			1,590			—
Unrecognized equity return (2)	(242		)	(242		)	—			(287		)	(287		)	—
Unamortized loss on reacquired debt	72			72			—			75			75			—
Pension and postretirement-related regulatory asset (3)	623			32			18			646			31			20
Hurricane Harvey restoration costs (4)	63			56			7			64			58			6
Regulatory assets related to TCJA (5)	48			33			15			48			33			15
Other long-term regulatory assets (6)	210			77			133			211			70			140
Total non-current regulatory assets	2,067			1,321			173			2,347			1,570			181
Total regulatory assets	2,122			1,321			228			2,477			1,570			311
Regulatory Liabilities:
Current regulatory liabilities (7)	43			6			37			24			22			2
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (5)	1,389			885			504			1,354			862			492
Estimated removal costs	885			279			606			878			285			593
Other long-term regulatory liabilities	247			101			146			232			116			116
Total non-current regulatory liabilities	2,521			1,265			1,256			2,464			1,263			1,201
Total regulatory liabilities	2,564			1,271			1,293			2,488			1,285			1,203
Total regulatory assets and liabilities, net	$	(442	)	$	50		$	(1,065	)	$	(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 June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $24 million and $10 million, respectively, of the allowed equity return. During the six months ended June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $45 million and $17 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 $5 million and $7 million as of June 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 June 30, 2018 and December 31, 2017.

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

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Derivative Instruments (Tables)

6 Months Ended

Jun. 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 activity:

				Three Months Ended June 30,				Six Months Ended June 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]

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 (CenterPoint Energy and CERC)

		June 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 fair value hedges:		(in millions)
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	$	—	$	3	$	13	$	1
Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	76		2		114		4
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	46		—		44		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	23		64		38		78
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	15		41		9		24
Total CERC		160		110		218		107
Indexed debt securities derivative	Current Liabilities	—		641		—		668
Total CenterPoint Energy		$	160	$	751	$	218	$	775

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,862 Bcf or a net 268 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of June 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 $82 million asset and a $130 million asset as of June 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 table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $32 million and $19 million, respectively.

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

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

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

	June 30, 2018									December 31, 2017
	Gross AmountsRecognized (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	$	99		$	(25	)	$	74		$	165		$	(55	)	$	110
Other Assets: Non-trading derivative assets	61			(15		)	46			53			(9		)	44
Current Liabilities: Non-trading derivative liabilities	(69		)	43			(26		)	(83		)	63			(20		)
Other Liabilities: Non-trading derivative liabilities	(41		)	29			(12		)	(24		)	20			(4		)
Total	$	50		$	32		$	82		$	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]

Hedge ineffectiveness is recorded as a component of natural gas expense and primarily results from differences in the location of the derivative instrument and the hedged item. Basis ineffectiveness arises from natural gas market price differences between the locations of the hedged inventory and the delivery location specified in the hedge instruments. The impact of natural gas derivatives designated as fair value hedges, the related hedged item, and natural gas derivatives not designated as hedging instruments are presented in the table below.

Income Statement Impact of Derivative Activity (CenterPoint Energy and CERC)

		Three Months Ended June 30,						Six Months Ended  June 30,
	Income Statement Location	2018			2017			2018			2017
Derivatives designated as fair value hedges:		(in millions)
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	$	13		$	3		$	13		$	12
Natural gas inventory	Gains (Losses) in Non-utility natural gas expense	(12		)	(4		)	(14		)	(14		)
Total CenterPoint Energy and CERC (1)		$	1		$	(1	)	$	(1	)	$	(2	)
Derivatives not designated as hedging instruments:
Natural gas derivatives	Gains (Losses) in Non-utility revenues	$	11		$	36		$	68		$	132
Natural gas derivatives	Gains (Losses) in Non-utility natural gas expense	(9		)	(9		)	(78		)	(82		)
Total CERC		2			27			(10		)	50
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(254		)	(13		)	(272		)	(23		)
Total CenterPoint Energy		$	(252	)	$	14		$	(282	)	$	27

(1) Hedge ineffectiveness results from the basis ineffectiveness discussed above, and excludes the impact to natural gas expense from timing ineffectiveness.  Timing ineffectiveness arises due to changes in the 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.  As the commodity contract nears the settlement date, spot-to-forward price differences should converge, which should reduce or eliminate the impact of this ineffectiveness on natural gas expense.

Disclosure of Credit Derivatives [Table Text Block]

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

	June 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

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

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

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

CenterPoint Energy

	June 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	$	586	$	—	$	—	$	—		$	586	$	963	$	—	$	—	$	—		$	963
Investments, including money market funds (2)	70		—		—		—			70		68		—		—		—			68
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	656	$	142	$	18	$	(40	)	$	776	$	1,045	$	161	$	57	$	(64	)	$	1,199
Liabilities
Indexed debt securities derivative	$	—	$	—	$	641	$	—		$	641	$	—	$	—	$	668	$	—		$	668
Natural gas derivatives (3)	—		105		5		(72		)	38		—		96		11		(83		)	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	646	$	(72	)	$	680	$	—	$	96	$	679	$	(83	)	$	692

Houston Electric

	June 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
Total assets	$	52	$	—	$	—	$	—	$	52	$	51	$	—	$	—	$	—	$	51

CERC

	June 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	$	2	$	—	$	—	$	—		$	2	$	3	$	—	$	—	$	—		$	3
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)	—		142		18		(40		)	120		—		161		57		(64		)	154
Hedged portion of natural gas inventory	—		—		—		—			—		14		—		—		—			14
Total assets	$	13	$	142	$	18	$	(40	)	$	133	$	28	$	161	$	57	$	(64	)	$	182
Liabilities
Natural gas derivatives (3)	$	—	$	105	$	5	$	(72	)	$	38	$	—	$	96	$	11	$	(83	)	$	24
Hedged portion of natural gas inventory	1		—		—		—			1		—		—		—		—			—
Total liabilities	$	1	$	105	$	5	$	(72	)	$	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 $32 million and $19 million as of June 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]

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 June 30,												Six Months Ended June 30,
	2018						2017						2018						2017
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)
Beginning balance	$	(662	)	$	12		$	(700	)	$	27		$	(622	)	$	46		$	(704	)	$	13
Total gains (losses)	(11		)	1			(6		)	7			(16		)	3			—			23
Total settlements	44			(1		)	—			—			11			(35		)	(4		)	(4		)
Transfers into Level 3	1			1			1			1			1			1			2			2
Transfers out of Level 3	—			—			(7		)	(7		)	(2		)	(2		)	(6		)	(6		)
Ending balance (1)	$	(628	)	$	13		$	(712	)	$	28		$	(628	)	$	13		$	(712	)	$	28
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:
	$	(9	)	$	3		$	(9	)	$	4		$	(23	)	$	(4	)	$	(2	)	$	21

(1) CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during either of the three or six months ended June 30, 2018 or 2017.

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

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

	June 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	$	8,256	$	4,919	$	2,722	$	8,679	$	4,753	$	2,457
Fair value	8,470		4,991		2,876		9,220		5,034		2,708

(1) Includes Securitization Bond debt.

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Unconsolidated Affiliate (CenterPoint Energy and CERC) (Tables)

6 Months Ended

Jun. 30, 2018

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Limited Partner Interest and Units Held in Enable:

	June 30, 2018
	Limited Partner Interest (1)		Common Units	Series A Preferred Units (2)
CERC Corp.	54.0	%	233,856,623	—
OGE	25.6	%	110,982,805	—
Public unitholders	20.4	%	88,225,208	—
CenterPoint Energy	—		—	14,520,000
Total units outstanding	100.0	%	433,064,636	14,520,000

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

(2) The carrying amount of the Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both June 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.

Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Operating revenues	$	805	$	626	$	1,553	$	1,292
Cost of sales, excluding depreciation and amortization	444		279		819		587
Operating income	126		122		265		262
Net income attributable to Enable	86		86		191		197
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s and CERC’s interest	$	46	$	47	$	103	$	107
Basis difference amortization (1)	12		12		24		24
CenterPoint Energy’s and CERC’s equity in earnings, net	$	58	$	59	$	127	$	131

(1) Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s and CERC’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s and CERC’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:

	June 30, 2018			December 31, 2017
	(in millions)
Current assets	$	432		$	416
Non-current assets	11,360			11,177
Current liabilities	1,258			1,279
Non-current liabilities	2,963			2,660
Non-controlling interest	11			12
Preferred equity	362			362
Enable partners’ equity	7,198			7,280
Reconciliation of Investment in Enable:
CenterPoint Energy’s and CERC’s ownership interest in Enable partners’ equity	$	3,887		$	3,935
CenterPoint Energy’s and CERC’s basis difference	(1,436		)	(1,463		)
CenterPoint Energy’s and CERC’s equity method investment in Enable	$	2,451		$	2,472

Distributions Received from Enable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Investment in Enable common units	$	75	$	75	$	149	$	149
Total CERC	75		75		149		149
Investment in Enable Series A Preferred Units	9		9		18		18
Total CenterPoint Energy	$	84	$	84	$	167	$	167

Transactions with Enable (CenterPoint Energy and CERC):

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Reimbursement of transition services (1)	$	1	$	1	$	3	$	3
Natural gas expenses, including transportation and storage costs	29		24		66		57

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

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

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

6 Months Ended

Jun. 30, 2018

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill [Table Text Block]

CenterPoint Energy’s and CERC’s goodwill by reportable business segment as of both June 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.

		June 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	$	(25	)	$	61	$	86	$	(21	)	$	65
Covenants not to compete	4	4		(2		)	2		4		(2		)	2
Other	Various	15		(9		)	6		15		(8		)	7
Total		$	105	$	(36	)	$	69	$	105	$	(31	)	$	74

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Amortization expense of intangible assets	$	2	$	1	$	5	$	3

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

6 Months Ended

Jun. 30, 2018

Investments, Debt and Equity Securities [Abstract]

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

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
	June 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

As a result, CenterPoint Energy recorded the following during the six months ended June 30, 2018:

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

(1)Cash of approximately $382 million was paid to ZENS note holders in July 2018.

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

	June 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

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

6 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Schedule of Debt [Table Text Block]

Debt Issuances. During the six months ended June 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

Schedule of Line of Credit Facilities [Table Text Block]

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

				June 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	$	—	—	%	$	—	$	6	$	855	1.88	%
Houston Electric	300			—		4		—		—		—		4		—		—
CERC Corp.	900			—		1		565		2.37	%	—		1		898		1.72	%
Total	$	2,900		$	—	$	11	$	565			$	—	$	11	$	1,753

(1) Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon 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 June 30, 2018 (2)	Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,700	(3)	1.250%	75%	(4) (5)	52.1%	March 3, 2022
March 3, 2016	Houston Electric	300			1.125%	65%	(5)	50.7%	March 3, 2022
March 3, 2016	CERC Corp.	900			1.250%	65%		37.8%	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 will increase to $3.3 billion upon the satisfaction of certain conditions described above.

(4) CenterPoint Energy’s financial covenant limit will return to 65% upon the earlier of (i) June 30, 2019 or (ii) 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.

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Income Taxes (Tables)

6 Months Ended

Jun. 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 June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
CenterPoint Energy	15	%	36	%	27	%	36	%
Houston Electric	21	%	36	%	22	%	36	%
CERC	22	%	35	%	22	%	37	%

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Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment [Table Text Block]

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

	(in millions)
Remaining six months of 2018	$	185
2019	264
2020	168
2021	82
2022	51
2023 and beyond	123

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Earnings Per Share (CenterPoint Energy) (Tables)

6 Months Ended

Jun. 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 (loss) per share calculations:

	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018		2017
	(in millions, except share and per share amounts)
Net income (loss)	$	(75	)	$	135	$	90	$	327
Basic weighted average shares outstanding	431,523,000			430,996,000		431,378,000		430,896,000
Plus: Incremental shares from assumed conversions:
Restricted stock (1)	—			2,801,000		3,029,000		2,801,000
Diluted weighted average shares	431,523,000			433,797,000		434,407,000		433,697,000
Basic earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.76
Diluted earnings (loss) per share
Net income (loss)	$	(0.17	)	$	0.31	$	0.21	$	0.75

(1)3,029,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the three months ended June 30, 2018 as their inclusion would be anti-dilutive.

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Reportable Business Segments (Tables)

6 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

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

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	X	X

Financial data for business segments is as follows:

CenterPoint Energy

	Three Months Ended June 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	$	854	(1)	$	—		$	181		$	752	(1)	$	—		$	171
Natural Gas Distribution	487			8			7			470			7			42
Energy Services	841			19			15			918			13			16
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	4			—			(16		)	3			—			11
Eliminations	—			(27		)	—			—			(20		)	—
Consolidated	$	2,186		$	—		$	187		$	2,143		$	—		$	240

	Six Months Ended June 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	$	1,605	(1)	$	—		$	296		$	1,391	(1)	$	—		$	257
Natural Gas Distribution	1,630			18			163			1,377			16			210
Energy Services	2,098			47			(11		)	2,103			24			51
Midstream Investments (2)	—			—			—			—			—			—
Other Operations	8			—			(10		)	7			—			13
Eliminations	—			(65		)	—			—			(40		)	—
Consolidated	$	5,341		$	—		$	438		$	4,878		$	—		$	531

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	169	$	167	$	330	$	319
Affiliates of Vistra Energy Corp.	59		53		113		100

CERC

	Three Months Ended June 30,
	2018							2017
	Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Natural Gas Distribution	$	487	$	8		$	7	$	470		$	7		$	42
Energy Services	841		19			15		918			13			16
Midstream Investments (2)	—		—			—		—			—			—
Other Operations	—		—			—		(1		)	—			1
Eliminations	—		(27		)	—		—			(20		)	—
Consolidated	$	1,328	$	—		$	22	$	1,387		$	—		$	59

	Six Months Ended June 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	$	1,630	$	18		$	163		$	1,377	$	16		$	210
Energy Services	2,098		47			(11		)	2,103		24			51
Midstream Investments (2)	—		—			—			—		—			—
Other Operations	—		—			1			—		—			(3		)
Eliminations	—		(65		)	—			—		(40		)	—
Consolidated	$	3,728	$	—		$	153		$	3,480	$	—		$	258

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	58	$	59	$	127	$	131

CenterPoint Energy and CERC

	Total Assets
	June 30, 2018							December 31, 2017
	CenterPoint  Energy				CERC			CenterPoint Energy				CERC
	(in millions)
Electric Transmission & Distribution	$	10,430			$	—		$	10,292			$	—
Natural Gas Distribution	6,501				6,501			6,608				6,608
Energy Services	1,256				1,256			1,521				1,521
Midstream Investments	2,451				2,451			2,472				2,472
Other Operations	2,311			(3)	89			2,497			(3)	70
Eliminations	(841		)		(655		)	(654		)		(559		)
Consolidated	$	22,108			$	9,642		$	22,736			$	10,112

(3) Includes pension and other postemployment-related regulatory assets of $577 million and $600 million, respectively, as of June 30, 2018 and December 31, 2017.

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 June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	169	$	167	$	330	$	319
Affiliates of Vistra Energy Corp.	59		53		113		100

Midstream Investments [Table Text Block]

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Enable	$	58	$	59	$	127	$	131

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Supplemental Disclosure of Cash Flow Information (Tables)

6 Months Ended

Jun. 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:

	Six Months Ended June 30,
	2018						2017
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	167	$	90	$	50	$	182	$	94	$	56
Income taxes, net	88		120		3		11		76		3
Non-cash transactions:
Accounts payable related to capital expenditures	133		75		69		106		75		44

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:

	June 30, 2018				December 31, 2017
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Cash and cash equivalents	$	328	$	253	$	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	$	366	$	291	$	296	$	274

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

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

6 Months Ended

Jun. 30, 2018

Related Party Transactions [Abstract]

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

The table below summarizes money pool activity:

	June 30, 2018						December 31, 2017
	Houston Electric			CERC			Houston Electric			CERC
	(in millions)
Money pool investments (borrowings) (1)	$	26		$	—		$	(60	)	$	(570	)
Weighted average interest rate	2.00		%	—		%	1.90		%	1.90		%

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

Schedule of Related Party Transactions [Table Text Block]

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

	Three Months Ended June 30,										Six Months Ended June 30,
	2018					2017					2018					2017
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)
Corporate service charges	$	47		$	35	$	44		$	32	$	91		$	69	$	86		$	63
Net affiliate service charges (billings)	(3		)	3		(4		)	4		(5		)	5		(5		)	5

Houston Electric and CERC paid dividends on their common shares and stock, respectively, to Utility Holding, LLC as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2018				2017				2018				2017
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Dividends paid	$	31	$	125	$	10	$	140	$	63	$	211	$	42	$	248

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 June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(in millions)
Affiliates of NRG	$	169	$	167	$	330	$	319
Affiliates of Vistra Energy Corp.	59		53		113		100

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Background and Basis of Presentation (Details)	Jun. 30, 2018 state shares
Enable Midstream Partners [Member]
Ownership percentage of equity method investment	54.00%
Enable Midstream Partners [Member] | Series A Preferred Units [Member]
Preferred units held | shares	14,520,000	[1]
Natural Gas Distribution [Member]
Number of states in which entity operates	6
Energy Services [Member]
Number of states in which entity operates	33

[1] The carrying amount of the Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both June 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.

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New Accounting Pronouncements (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 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 2016-18 [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	$ 15	$ 17	29	34
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	(15)	(17)	(29)	(34)
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	8	7	15	15
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	(8)	(7)	(15)	(15)
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	4	6	8	11
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	$ (4)	$ (6)	$ (8)	$ (11)

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Proposed Merger with Vectren (CenterPoint Energy) (Details) - USD ($) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
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	$ 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	248
Long-term debt, including current maturities	2,000
Termination fee	150
CenterPoint Energy [Member]
Termination fee	$ 210

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Revenue Recognition (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Revenue from contracts		$ 1,449	$ 1,338	$ 3,575	$ 3,050
Derivatives income		782	815	1,885	1,870
Other (3)	[1]	(18)	10	(54)	(2)
Total revenues		2,186	2,143	5,341	4,878
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(27)	(20)	(65)	(40)
Electric Transmission and Distribution [Member]
Disaggregation of Revenue [Line Items]
Total revenues	[2]	854	752	1,605	1,391
Electric Transmission and Distribution [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		0	0	0	0
Natural Gas Distribution [Member]
Disaggregation of Revenue [Line Items]
Total revenues		487	470	1,630	1,377
Natural Gas Distribution [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(8)	(7)	(18)	(16)
Energy Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues		841	918	2,098	2,103
Energy Services [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(19)	(13)	(47)	(24)
Other Operations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		4	3	8	7
Other Operations [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		0	0	0	0
Reportable Subsegments [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[3]	(8)	(7)	(18)	(16)
Derivatives income	[4]	(19)	(13)	(47)	(24)
Total revenues		(27)	(20)	(65)	(40)
Reportable Subsegments [Member] | Electric Transmission and Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[3]	860	758	1,621	1,402
Derivatives income	[3]	0	0	(4)	1
Other (3)	[1],[3]	(6)	(6)	(12)	(12)
Total revenues	[3]	854	752	1,605	1,391
Reportable Subsegments [Member] | Natural Gas Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[3]	509	463	1,695	1,388
Derivatives income	[3]	0	0	0	0
Other (3)	[1],[3]	(14)	14	(47)	5
Total revenues	[3]	487	470	1,630	1,377
Reportable Subsegments [Member] | Energy Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[4]	78	116	256	258
Derivatives income	[4]	782	815	1,889	1,869
Other (3)	[1],[4]	0	0	0	0
Total revenues	[4]	841	918	2,098	2,103
Reportable Subsegments [Member] | Other Operations [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[4]	2	1	3	2
Derivatives income	[4]	0	0	0	0
Other (3)	[1],[4]	2	2	5	5
Total revenues	[4]	4	3	8	7
Houston Electric [Member]
Disaggregation of Revenue [Line Items]
Total revenues		854	752	1,609	1,390
Houston Electric [Member] | Reportable Subsegments [Member] | Electric Transmission and Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts		860	758	1,621	1,402
Other (3)	[1]	(6)	(6)	(12)	(12)
Total revenues		854	752	1,609	1,390
CERC Corp [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts		587	579	1,951	1,646
Derivatives income		782	815	1,889	1,869
Other (3)	[1]	(14)	13	(47)	5
Total revenues		1,328	1,387	3,728	3,480
CERC Corp [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(27)	(20)	(65)	(40)
CERC Corp [Member] | Natural Gas Distribution [Member]
Disaggregation of Revenue [Line Items]
Total revenues		487	470	1,630	1,377
CERC Corp [Member] | Natural Gas Distribution [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(8)	(7)	(18)	(16)
CERC Corp [Member] | Energy Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues		841	918	2,098	2,103
CERC Corp [Member] | Energy Services [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		(19)	(13)	(47)	(24)
CERC Corp [Member] | Other Operations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		0	(1)	0	0
CERC Corp [Member] | Other Operations [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Total revenues		0	0	0	0
CERC Corp [Member] | Reportable Subsegments [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[3]	(8)	(7)	(18)	(16)
Derivatives income	[4]	(19)	(13)	(47)	(24)
Total revenues		(27)	(20)	(65)	(40)
CERC Corp [Member] | Reportable Subsegments [Member] | Natural Gas Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[3]	509	463	1,695	1,388
Derivatives income	[3]	0	0	0	0
Other (3)	[1],[3]	(14)	14	(47)	5
Total revenues	[3]	487	470	1,630	1,377
CERC Corp [Member] | Reportable Subsegments [Member] | Energy Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[4]	78	116	256	258
Derivatives income	[4]	782	815	1,889	1,869
Other (3)	[1],[4]	0	0	0	0
Total revenues	[4]	841	918	2,098	2,103
CERC Corp [Member] | Reportable Subsegments [Member] | Other Operations [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts	[4]	0	0	0	0
Derivatives income	[4]	0	0	0	0
Other (3)	[1],[4]	0	(1)	0	0
Total revenues	[4]	$ 0	$ (1)	$ 0	$ 0

[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:

[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.

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Employee Benefit Plans (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Defined Benefit Plan, Change in Accumulated Comprehensive Loss [Roll Forward]
Beginning Balance		$ (65)	$ (71)	$ (66)	$ (72)
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (1)	[1]	1	1	1	1
Actuarial losses (1)	[1]	1	1	3	3
Tax expense		0	(1)	(1)	(2)
Net current period other comprehensive income		2	1	3	2
Ending Balance		(63)	(70)	(63)	(70)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic cost		15	25	30	48
Total contributions expected in current year		67		67
Total contributions to the plans during the period		2		64
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic cost		2	2	3	4
Total contributions expected in current year		16		16
Total contributions to the plans during the period		3		7
Operation and maintenance expense [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost (1)	[2]	9	9	18	18
Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost (1)	[2]	1	1	1	1
Other, net [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost (2)	[3]	19	22	39	44
Expected return on plan assets (2)	[3]	(26)	(24)	(53)	(48)
Amortization of prior service cost (credit) (2)	[3]	2	3	4	5
Amortization of net loss (2)	[3]	11	15	22	29
Other, net [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost (2)	[3]	4	4	7	8
Expected return on plan assets (2)	[3]	(2)	(2)	(3)	(3)
Amortization of prior service cost (credit) (2)	[3]	(1)	(1)	(2)	(2)
Houston Electric [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic cost		(1)	0	(1)	0
Total contributions expected in current year		10		10
Total contributions to the plans during the period		2		4
Houston Electric [Member] | Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost (1)	[2]	0	0	0	0
Houston Electric [Member] | Other, net [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost (2)	[3]	2	2	4	4
Expected return on plan assets (2)	[3]	(1)	(1)	(2)	(2)
Amortization of prior service cost (credit) (2)	[3]	(2)	(1)	(3)	(2)
CERC Corp [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic cost		1	2	2	3
Total contributions expected in current year		5		5
Total contributions to the plans during the period		1		2
CERC Corp [Member] | Operation and maintenance expense [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost (1)	[2]	0	0	0	0
CERC Corp [Member] | Other, net [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost (2)	[3]	1	1	2	2
Expected return on plan assets (2)	[3]	(1)	0	(1)	0
Amortization of prior service cost (credit) (2)	[3]	$ 1	$ 1	$ 1	$ 1

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

[2] Included in Operation and maintenance expense in the Registrants’ Condensed Statements of Consolidated Income.

[3] Included in Other, net in the Registrants’ Condensed Statements of Consolidated Income.

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Regulatory Accounting (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Securitized regulatory assets		$ 1,293		$ 1,293		$ 1,590
Unrecognized equity return (2)	[1]	(242)		(242)		(287)
Unamortized loss on reacquired debt		72		72		75
Regulatory assets		2,067		2,067		2,347
Total regulatory assets		2,122		2,122		2,477
Regulatory liabilities		2,521		2,521		2,464
Total regulatory liabilities		2,564		2,564		2,488
Total regulatory assets and liabilities, net		(442)		(442)		(11)
Houston Electric [Member]
Securitized regulatory assets		1,293		1,293		1,590
Unrecognized equity return (2)	[1]	(242)		(242)		(287)
Unamortized loss on reacquired debt		72		72		75
Regulatory assets		1,321		1,321		1,570
Total regulatory assets		1,321		1,321		1,570
Regulatory liabilities		1,265		1,265		1,263
Total regulatory liabilities		1,271		1,271		1,285
Total regulatory assets and liabilities, net		50		50		285
Amount of allowed equity return on the true-up balance that was recognized in the period		24	$ 10	45	$ 17
CERC Corp [Member]
Securitized regulatory assets		0		0		0
Unrecognized equity return (2)	[1]	0		0		0
Unamortized loss on reacquired debt		0		0		0
Regulatory assets		173		173		181
Total regulatory assets		228		228		311
Regulatory liabilities		1,256		1,256		1,201
Total regulatory liabilities		1,293		1,293		1,203
Total regulatory assets and liabilities, net		(1,065)		(1,065)		(892)
Hurricane Harvey [Member]
Regulatory assets	[2]	63		63		64
Hurricane Harvey [Member] | Houston Electric [Member]
Regulatory assets	[2]	56		56		58
Hurricane Harvey [Member] | CERC Corp [Member]
Regulatory assets	[2]	7		7		6
Prepaid expenses and other current assets [Member]
Current regulatory assets (1)	[3]	55		55		130
Prepaid expenses and other current assets [Member] | Houston Electric [Member]
Current regulatory assets (1)	[3]	0		0		0
Prepaid expenses and other current assets [Member] | CERC Corp [Member]
Current regulatory assets (1)	[3]	55		55		130
Other current liabilities [Member]
Current regulatory liabilities (7)	[4]	43		43		24
Other current liabilities [Member] | Houston Electric [Member]
Current regulatory liabilities (7)	[4]	6		6		22
Other current liabilities [Member] | CERC Corp [Member]
Current regulatory liabilities (7)	[4]	37		37		2
Pension and Other Postretirement Plans Costs [Member]
Regulatory assets	[5]	623		623		646
Pension and Other Postretirement Plans Costs [Member] | Houston Electric [Member]
Regulatory assets	[5]	32		32		31
Pension and Other Postretirement Plans Costs [Member] | CERC Corp [Member]
Regulatory assets	[5]	18		18		20
Amounts related to TCJA [Member]
Regulatory assets	[6]	48		48		48
Amounts related to TCJA [Member] | Houston Electric [Member]
Regulatory assets	[6]	33		33		33
Amounts related to TCJA [Member] | CERC Corp [Member]
Regulatory assets	[6]	15		15		15
Other Regulatory Assets (Liabilities) [Member]
Regulatory assets	[7]	210		210		211
Other Regulatory Assets (Liabilities) [Member] | Houston Electric [Member]
Regulatory assets	[7]	77		77		70
Other Regulatory Assets (Liabilities) [Member] | CERC Corp [Member]
Regulatory assets	[7]	133		133		140
Amounts related to TCJA [Member]
Regulatory liabilities	[6]	1,389		1,389		1,354
Amounts related to TCJA [Member] | Houston Electric [Member]
Regulatory liabilities	[6]	885		885		862
Amounts related to TCJA [Member] | CERC Corp [Member]
Regulatory liabilities	[6]	504		504		492
Removal Costs [Member]
Regulatory liabilities		885		885		878
Removal Costs [Member] | Houston Electric [Member]
Regulatory liabilities		279		279		285
Removal Costs [Member] | CERC Corp [Member]
Regulatory liabilities		606		606		593
Other Regulatory Assets (Liabilities) [Member]
Regulatory liabilities		247		247		232
Other Regulatory Assets (Liabilities) [Member] | Houston Electric [Member]
Regulatory liabilities		101		101		116
Other Regulatory Assets (Liabilities) [Member] | CERC Corp [Member]
Regulatory liabilities		146		146		116
Natural Gas Distribution [Member] | Pension and Other Postretirement Plans Costs [Member]
Remaining amounts of regulatory assets for which no return on investment during recovery period is provided		$ 5		$ 5		$ 7

[1] The unrecognized equity return will be recognized as it is recovered in rates through 2024. During the three months ended June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $24 million and $10 million, respectively, of the allowed equity return. During the six months ended June 30, 2018 and 2017, CenterPoint Energy and Houston Electric recognized approximately $45 million and $17 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 the Registrants’ 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 $5 million and $7 million as of June 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 June 30, 2018 and December 31, 2017.

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Derivative Instruments Derivatives and hedging (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 26, 2018	Feb. 28, 2018
Derivatives, Fair Value [Line Items]
Weather hedges term				10 years
Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges	[1]	$ 0	$ 0	$ (4)	$ 1
2018 to 2019 [Member] | Natural Gas Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather hedge bilateral cap amount				9
2018 to 2019 [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather hedge bilateral cap amount				8
2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges		0	0	0	0
2017 to 2018 [Member] | Natural Gas Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather hedge bilateral cap amount				8
2017 to 2018 [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather hedge bilateral cap amount				9
2017 to 2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges		0	0	(4)	0
2016 to 2017 [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather hedge bilateral cap amount				9
2016 to 2017 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges		0	0	0	1
Houston Electric [Member] | January thru February [Member] | Treasury Lock [Member]
Derivatives, Fair Value [Line Items]
Aggregate notional amount		200		200
Effective portion of realized gains (losses)				5
CERC Corp [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges	[1]	0	0	0	0
CERC Corp [Member] | 2018 to 2019 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges		0	0	0	0
CERC Corp [Member] | 2017 to 2018 [Member] | Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member] | Natural Gas Distribution [Member]
Derivatives, Fair Value [Line Items]
Recognized gain (loss) on weather hedges		0	$ 0	0	$ 0
CERC Corp [Member] | March [Member] | Treasury Lock [Member]
Derivatives, Fair Value [Line Items]
Aggregate notional amount		$ 450		450
Effective portion of realized gains (losses)				$ (1)
General Mortgage Bonds Due 2048 [Member] | Houston Electric [Member]
Derivatives, Fair Value [Line Items]
Principal amount of debt issued							$ 400
Senior Notes [Member] | CERC Corp [Member]
Derivatives, Fair Value [Line Items]
Principal amount of debt issued						$ 600

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

XML

Derivative Instruments Derivative Fair Values (Details) $ in Millions		3 Months Ended		6 Months Ended		12 Months Ended
		Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) Bcf	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($) Bcf
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value		$ 160		$ 160		$ 218
Derivative Liabilities Fair Value		751		751		775
Gain (loss) on derivative instruments not designated as hedging instruments		(252)	$ 14	(282)	$ 27
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position		2		2		2
Fair value of collateral already posted		0		0		0
Additional collateral required to be posted if credit risk contingent features triggered		1		1		$ 2
Gains (Losses) in Non-utility natural gas expense [Member]
Derivatives, Fair Value [Line Items]
Change in unrealized gain (loss) on hedged item in fair value hedge		(12)	(4)	(14)	(14)
Gain (loss) on fair value hedges recognized in earnings	[1]	1	(1)	$ (1)	(2)
Energy Related Derivative [Member]
Derivatives, Fair Value [Line Items]
Derivative gross volume notional amount (in Bcf) | Bcf				1,862		1,795
Net amount presented in the consolidated balance sheets	[2]	82		$ 82		$ 130
Gross Amounts Recognized	[3]	50		50		111
Gross Amounts Offset in the Consolidated Balance Sheets		32		32		19
Energy Related Derivative [Member] | Gains (Losses) in Non-utility natural gas expense [Member]
Derivatives, Fair Value [Line Items]
Change in unrealized gain (loss) on fair value hedging instruments		13	3	13	12
Energy Related Derivative [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts Recognized	[3]	99		99		165
Gross Amounts Offset		(25)		(25)		(55)
Derivative Asset	[2]	74		74		110
Energy Related Derivative [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts Recognized	[3]	61		61		53
Gross Amounts Offset		(15)		(15)		(9)
Derivative Asset	[2]	46		46		44
Energy Related Derivative [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts Recognized	[3]	(69)		(69)		(83)
Gross Amounts Offset		43		43		63
Derivative Liability	[2]	(26)		(26)		(20)
Energy Related Derivative [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts Recognized	[3]	(41)		(41)		(24)
Gross Amounts Offset		29		29		20
Derivative Liability	[2]	(12)		$ (12)		$ (4)
Energy Related Derivative [Member] | Long [Member]
Derivatives, Fair Value [Line Items]
Derivative gross volume notional amount (in Bcf) | Bcf				268		224
IDS Derivative [Member] | Gains (losses) in Other Income (Expense) [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on derivative instruments not designated as hedging instruments		(254)	(13)	$ (272)	(23)
IDS Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value		0		0		$ 0
Derivative Liabilities Fair Value		641		641		668
CERC Corp [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value		160		160		218
Derivative Liabilities Fair Value		110		110		107
Gain (loss) on derivative instruments not designated as hedging instruments		2	27	(10)	50
CERC Corp [Member] | Energy Related Derivative [Member] | Gains (Losses) in Non-utility revenues [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on derivative instruments not designated as hedging instruments		11	36	68	132
CERC Corp [Member] | Energy Related Derivative [Member] | Gains (Losses) in Non-utility natural gas expense [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on derivative instruments not designated as hedging instruments		(9)	$ (9)	(78)	$ (82)
CERC Corp [Member] | Energy Related Derivative [Member] | Designated as Fair Value Hedge [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value	[4],[5],[6]	0		0		13
Derivative Liabilities Fair Value	[4],[5],[6]	3		3		1
CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value	[4],[5],[6]	76		76		114
Derivative Liabilities Fair Value	[4],[5],[6]	2		2		4
CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value	[4],[5],[6]	46		46		44
Derivative Liabilities Fair Value	[4],[5],[6]	0		0		0
CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value	[4],[5],[6]	23		23		38
Derivative Liabilities Fair Value	[4],[5],[6]	64		64		78
CERC Corp [Member] | Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets Fair Value	[4],[5],[6]	15		15		9
Derivative Liabilities Fair Value	[4],[5],[6]	$ 41		$ 41		$ 24

[1] Hedge ineffectiveness results from the basis ineffectiveness discussed above, and excludes the impact to natural gas expense from timing ineffectiveness. Timing ineffectiveness arises due to changes in the 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. As the commodity contract nears the settlement date, spot-to-forward price differences should converge, which should reduce or eliminate the impact of this ineffectiveness on natural gas expense.

[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.

[3] Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.

[4] Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

[5] Natural gas contracts are presented on a net basis in 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 $82 million asset and a $130 million asset as of June 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 table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, impacted by collateral netting of $32 million and $19 million, respectively.

[6] The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,862 Bcf or a net 268 Bcf long position and 1,795 Bcf or a net 224 Bcf long position as of June 30, 2018 and December 31, 2017, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

XML

Fair Value Measurements (Details)		3 Months Ended		6 Months Ended
		Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair value amount of Level 1 to Level 2 assets transferred		$ 0		$ 0
Fair value amount of Level 2 to Level 1 assets transferred		0		0
Fair value amount of Level 1 to Level 2 liabilities transferred		0		0
Fair value amount of Level 2 to Level 1 liabilities transferred		0		0
Assets
Total derivative assets, netting adjustment	[1]	(40,000,000)		(40,000,000)		$ (64,000,000)
Total assets		776,000,000		776,000,000		1,199,000,000
Liabilities
Total derivative liabilities, netting adjustment	[1]	(72,000,000)		(72,000,000)		(83,000,000)
Total liabilities		680,000,000		680,000,000		692,000,000
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		(662,000,000)	$ (700,000,000)	(622,000,000)	$ (704,000,000)
Total gains (losses)		(11,000,000)	(6,000,000)	(16,000,000)	0
Total settlements		44,000,000	0	11,000,000	(4,000,000)
Transfers into Level 3		1,000,000	1,000,000	1,000,000	2,000,000
Transfers out of Level 3		0	(7,000,000)	(2,000,000)	(6,000,000)
Ending balance (1)	[2]	(628,000,000)	(712,000,000)	(628,000,000)	(712,000,000)
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:		(9,000,000)	(9,000,000)	(23,000,000)	(2,000,000)
Carrying Amount [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities	[3]	8,256,000,000		8,256,000,000		8,679,000,000
Fair Value [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities	[3]	8,470,000,000		8,470,000,000		9,220,000,000
Natural gas derivatives [Member]
Assets
Derivative fair value offsets, net		32,000,000		32,000,000		19,000,000
Fair Value, Inputs, Level 1 [Member]
Assets
Total assets		656,000,000		656,000,000		1,045,000,000
Liabilities
Total liabilities		1,000,000		1,000,000		0
Fair Value, Inputs, Level 2 [Member]
Assets
Total assets		142,000,000		142,000,000		161,000,000
Liabilities
Total liabilities		105,000,000		105,000,000		96,000,000
Fair Value, Inputs, Level 3 [Member]
Assets
Total assets		18,000,000		18,000,000		57,000,000
Liabilities
Total liabilities		646,000,000		$ 646,000,000		679,000,000
Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member] | Minimum [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair value inputs (price per MMBtu)				1.04
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)				3.31
Fair Value, Measurements, Recurring [Member]
Assets
Corporate equities		586,000,000		$ 586,000,000		963,000,000
Investments, including money market funds (2)	[4]	70,000,000		70,000,000		68,000,000
Hedged portion of natural gas inventory		0		0		14,000,000
Liabilities
Hedged portion of natural gas inventory		1,000,000		1,000,000		0
Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member]
Liabilities
Derivative liabilities, netting adjustment	[1]	0		0		0
Derivative liabilities		641,000,000		641,000,000		668,000,000
Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member]
Assets
Derivative asset, netting adjustment	[1],[5]	(40,000,000)		(40,000,000)		(64,000,000)
Derivative assets	[5]	120,000,000		120,000,000		154,000,000
Liabilities
Derivative liabilities, netting adjustment	[1],[5]	(72,000,000)		(72,000,000)		(83,000,000)
Derivative liabilities	[5]	38,000,000		38,000,000		24,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Corporate equities		586,000,000		586,000,000		963,000,000
Investments, including money market funds (2)	[4]	70,000,000		70,000,000		68,000,000
Hedged portion of natural gas inventory		0		0		14,000,000
Liabilities
Hedged portion of natural gas inventory		1,000,000		1,000,000		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | IDS Derivative [Member]
Liabilities
Derivative liability		0		0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	0		0		0
Liabilities
Derivative liability	[5]	0		0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Corporate equities		0		0		0
Investments, including money market funds (2)	[4]	0		0		0
Hedged portion of natural gas inventory		0		0		0
Liabilities
Hedged portion of natural gas inventory		0		0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | IDS Derivative [Member]
Liabilities
Derivative liability		0		0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	142,000,000		142,000,000		161,000,000
Liabilities
Derivative liability	[5]	105,000,000		105,000,000		96,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Corporate equities		0		0		0
Investments, including money market funds (2)	[4]	0		0		0
Hedged portion of natural gas inventory		0		0		0
Liabilities
Hedged portion of natural gas inventory		0		0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | IDS Derivative [Member]
Liabilities
Derivative liability		641,000,000		641,000,000		668,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	18,000,000		18,000,000		57,000,000
Liabilities
Derivative liability	[5]	5,000,000		5,000,000		11,000,000
CERC Corp [Member]
Assets
Total derivative assets, netting adjustment	[1]	(40,000,000)		(40,000,000)		(64,000,000)
Total assets		133,000,000		133,000,000		182,000,000
Liabilities
Total derivative liabilities, netting adjustment	[1]	(72,000,000)		(72,000,000)		(83,000,000)
Total liabilities		39,000,000		39,000,000		24,000,000
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		12,000,000	27,000,000	46,000,000	13,000,000
Total gains (losses)		1,000,000	7,000,000	3,000,000	23,000,000
Total settlements		(1,000,000)	0	(35,000,000)	(4,000,000)
Transfers into Level 3		1,000,000	1,000,000	1,000,000	2,000,000
Transfers out of Level 3		0	(7,000,000)	(2,000,000)	(6,000,000)
Ending balance (1)	[2]	13,000,000	28,000,000	13,000,000	28,000,000
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:		3,000,000	$ 4,000,000	(4,000,000)	$ 21,000,000
CERC Corp [Member] | Carrying Amount [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities		2,722,000,000		2,722,000,000		2,457,000,000
CERC Corp [Member] | Fair Value [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities		2,876,000,000		2,876,000,000		2,708,000,000
CERC Corp [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Total assets		13,000,000		13,000,000		28,000,000
Liabilities
Total liabilities		1,000,000		1,000,000		0
CERC Corp [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Total assets		142,000,000		142,000,000		161,000,000
Liabilities
Total liabilities		105,000,000		105,000,000		96,000,000
CERC Corp [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Total assets		18,000,000		18,000,000		57,000,000
Liabilities
Total liabilities		5,000,000		5,000,000		11,000,000
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member]
Assets
Corporate equities		2,000,000		2,000,000		3,000,000
Investments, including money market funds (2)	[4]	11,000,000		11,000,000		11,000,000
Hedged portion of natural gas inventory		0		0		14,000,000
Liabilities
Hedged portion of natural gas inventory		1,000,000		1,000,000		0
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member]
Assets
Derivative asset, netting adjustment	[1],[5]	(40,000,000)		(40,000,000)		(64,000,000)
Derivative assets	[5]	120,000,000		120,000,000		154,000,000
Liabilities
Derivative liabilities, netting adjustment	[1],[5]	(72,000,000)		(72,000,000)		(83,000,000)
Derivative liabilities	[5]	38,000,000		38,000,000		24,000,000
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Corporate equities		2,000,000		2,000,000		3,000,000
Investments, including money market funds (2)	[4]	11,000,000		11,000,000		11,000,000
Hedged portion of natural gas inventory		0		0		14,000,000
Liabilities
Hedged portion of natural gas inventory		1,000,000		1,000,000		0
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	0		0		0
Liabilities
Derivative liability	[5]	0		0		0
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Corporate equities		0		0		0
Investments, including money market funds (2)	[4]	0		0		0
Hedged portion of natural gas inventory		0		0		0
Liabilities
Hedged portion of natural gas inventory		0		0		0
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	142,000,000		142,000,000		161,000,000
Liabilities
Derivative liability	[5]	105,000,000		105,000,000		96,000,000
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Corporate equities		0		0		0
Investments, including money market funds (2)	[4]	0		0		0
Hedged portion of natural gas inventory		0		0		0
Liabilities
Hedged portion of natural gas inventory		0		0		0
CERC Corp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural gas derivatives [Member]
Assets
Derivative asset	[5]	18,000,000		18,000,000		57,000,000
Liabilities
Derivative liability	[5]	5,000,000		5,000,000		11,000,000
Houston Electric [Member]
Assets
Total derivative assets, netting adjustment		0		0		0
Total assets		52,000,000		52,000,000		51,000,000
Houston Electric [Member] | Carrying Amount [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities	[3]	4,919,000,000		4,919,000,000		4,753,000,000
Houston Electric [Member] | Fair Value [Member]
Estimated Fair Value of Financial Instruments
Long-term debt, including current maturities	[3]	4,991,000,000		4,991,000,000		5,034,000,000
Houston Electric [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Total assets		52,000,000		52,000,000		51,000,000
Houston Electric [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Total assets		0		0		0
Houston Electric [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Total assets		0		0		0
Houston Electric [Member] | Fair Value, Measurements, Recurring [Member]
Assets
Investments, including money market funds (2)	[4]	52,000,000		52,000,000		51,000,000
Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Investments, including money market funds (2)	[4]	52,000,000		52,000,000		51,000,000
Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Investments, including money market funds (2)	[4]	0		0		0
Houston Electric [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Investments, including money market funds (2)	[4]	$ 0		$ 0		$ 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 $32 million and $19 million as of June 30, 2018 and December 31, 2017, respectively, posted with the same counterparties.

[2] CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during either of the three or six months ended June 30, 2018 or 2017.

[3] Includes Securitization Bond debt.

[4] Amounts are included in Prepaid expenses and other current assets in the Condensed Consolidated Balance Sheets.

[5] Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

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Unconsolidated Affiliate (CenterPoint Energy and CERC) (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Enable Units [Abstract]
Preferred units – unconsolidated affiliate		$ 363		$ 363		$ 363
Percentage of sales that trigger right of first refusal				5.00%
Enable Distributions [Abstract]
Total distributions received from Enable		84	$ 84	$ 167	$ 167
Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]
CenterPoint Energy’s and CERC’s equity in earnings, net		58	59	127	131
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]
CenterPoint Energy’s and CERC’s equity method investment in Enable		2,451		2,451		2,472
CERC Corp [Member]
Enable Distributions [Abstract]
Total distributions received from Enable		75	75	149	149
Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]
CenterPoint Energy’s and CERC’s equity in earnings, net		58	59	127	131
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]
CenterPoint Energy’s and CERC’s equity method investment in Enable		$ 2,451		$ 2,451		2,472
OGE [Member]
Enable Units [Abstract]
Percentage of sales that trigger right of first refusal				5.00%
Enable Midstream Partners [Member]
Enable Partnership Interest [Abstract]
Ownership percentage of equity method investment		54.00%		54.00%
Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]
Operating revenues		$ 805	626	$ 1,553	1,292
Cost of sales, excluding depreciation and amortization		444	279	819	587
Operating income		126	122	265	262
Net income attributable to Enable		86	86	191	197
CenterPoint Energy’s and CERC’s interest		46	47	103	107
Basis difference amortization (1)	[1]	12	12	24	24
CenterPoint Energy’s and CERC’s equity in earnings, net		58	59	$ 127	131
Basis difference amortization period				31 years
Equity Method Investment, Summarized Financial Information, Assets and Liabilities [Abstract]
Current assets		432		$ 432		416
Non-current assets		11,360		11,360		11,177
Current liabilities		1,258		1,258		1,279
Non-current liabilities		2,963		2,963		2,660
Non-controlling interest		11		11		12
Preferred equity		362		362		362
Enable partners’ equity		7,198		7,198		7,280
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]
CenterPoint Energy’s and CERC’s ownership interest in Enable partners’ equity		3,887		3,887		3,935
CenterPoint Energy’s and CERC’s basis difference		(1,436)		(1,436)		(1,463)
CenterPoint Energy’s and CERC’s equity method investment in Enable		2,451		2,451		2,472
Enable Midstream Partners [Member] | Common Units [Member]
Enable Distributions [Abstract]
Distributions received from Enable equity method investment		75	75	149	149
Enable Midstream Partners [Member] | Series A Preferred Units [Member]
Enable Distributions [Abstract]
Distributions received from Enable cost method investment		$ 9	9	$ 18	18
Enable Midstream Partners [Member] | CERC Corp [Member]
Enable Partnership Interest [Abstract]
Ownership percentage of equity method investment	[2]	54.00%		54.00%
Enable Midstream Partners [Member]
Enable Partnership Interest [Abstract]
Limited partner ownership interest	[2]			100.00%
Enable Distributions [Abstract]
Maximum incentive distribution right				50.00%
Enable Midstream Partners [Member] | CERC Corp [Member]
Enable Units [Abstract]
Management rights ownership percentage				50.00%
Enable Distributions [Abstract]
Incentive distribution right				40.00%
Enable Midstream Partners [Member] | OGE [Member]
Enable Partnership Interest [Abstract]
Limited partner ownership interest	[2]			25.60%
Enable Units [Abstract]
Management rights ownership percentage				50.00%
Enable Distributions [Abstract]
Incentive distribution right				60.00%
Enable Midstream Partners [Member] | Public unitholders [Member]
Enable Partnership Interest [Abstract]
Limited partner ownership interest	[2]			20.40%
Enable Midstream Partners [Member] | Minimum [Member]
Enable Distributions [Abstract]
Incentive distribution per unit				$ 0.2875
Enable Midstream Partners [Member] | Maximum [Member]
Enable Distributions [Abstract]
Incentive distribution per unit				$ 0.330625
Common Units [Member] | Enable Midstream Partners [Member] | CERC Corp [Member]
Enable Units [Abstract]
Limited partner interest units held		233,856,623		233,856,623
Common Units [Member] | Enable Midstream Partners [Member]
Enable Units [Abstract]
Limited partner interest units held		433,064,636		433,064,636
Common Units [Member] | Enable Midstream Partners [Member] | OGE [Member]
Enable Units [Abstract]
Limited partner interest units held		110,982,805		110,982,805
Common Units [Member] | Enable Midstream Partners [Member] | Public unitholders [Member]
Enable Units [Abstract]
Limited partner interest units held		88,225,208		88,225,208
Series A Preferred Units [Member] | Enable Midstream Partners [Member]
Enable Units [Abstract]
Preferred Units Held	[3]	14,520,000		14,520,000
Transitional Service [Member] | Enable Midstream Partners [Member]
Transactions with Enable [Abstract]
Reimbursement of transition services (1)	[4]	$ 1	1	$ 3	3
Accounts receivable for amounts billed for transition services		3		3		1
Natural Gas Expenses [Member] | Enable Midstream Partners [Member]
Transactions with Enable [Abstract]
Natural gas expenses, including transportation and storage costs		29	$ 24	66	$ 57
Accounts payable for natural gas purchases from Enable		$ 8		$ 8		$ 13

[1] Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s and CERC’s share of Enable’s earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s and CERC’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.

[2] Excluding the Series A Preferred Units owned by CenterPoint Energy.

[3] The carrying amount of the Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of both June 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] Represents amounts billed under the Transition Agreements for certain support services provided to Enable. Actual transition services costs are recorded net of reimbursement.

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Goodwill and Other Intangibles (CenterPoint Energy and CERC) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended		12 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Goodwill [Line Items]
Goodwill		$ 867		$ 867		$ 867
Intangible assets gross carrying amount		105		105		105
Intangible assets accumulated amortization		(36)		(36)		(31)
Net intangible assets		69		69		74
Amortization expense of intangible assets		2	$ 1	5	$ 3
Natural Gas Distribution [Member]
Goodwill [Line Items]
Goodwill		746		746		746
Energy Services [Member]
Goodwill [Line Items]
Goodwill	[1]	110		110		110
Accumulated goodwill impairment charge recorded in 2012		252		252		252
Other Operations [Member]
Goodwill [Line Items]
Goodwill		11		$ 11		$ 11
Customer Relationships [Member]
Goodwill [Line Items]
Intangible asset useful lives				15 years		15 years
Intangible assets gross carrying amount		86		$ 86		$ 86
Intangible assets accumulated amortization		(25)		(25)		(21)
Net intangible assets		61		$ 61		$ 65
Noncompete Agreements [Member]
Goodwill [Line Items]
Intangible asset useful lives				4 years		4 years
Intangible assets gross carrying amount		4		$ 4		$ 4
Intangible assets accumulated amortization		(2)		(2)		(2)
Net intangible assets		2		2		2
Other Intangible Assets [Member]
Goodwill [Line Items]
Intangible assets gross carrying amount		15		15		15
Intangible assets accumulated amortization		(9)		(9)		(8)
Net intangible assets		$ 6		$ 6		$ 7

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

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Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy) (Details) $ / shares in Units, $ in Millions			6 Months Ended
		Jul. 17, 2018 USD ($)	Jun. 30, 2018 USD ($) shares $ / shares	Jun. 30, 2017 USD ($)	Jun. 14, 2018 $ / shares shares	Jan. 31, 2018 $ / shares	Dec. 31, 2017 USD ($) shares	Nov. 26, 2017 $ / shares
Cash paid per share exchanged | $ / shares			$ 72.00
Distribution To ZENS holders			$ 16	$ 0
Due to ZENS note holders			382				$ 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			$ 484
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
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
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
AT&T To Acquire Time Warner [Member]
Due to ZENS note holders	[1]		$ 382
Indexed debt – reduction			(95)
Indexed debt securities derivative – reduction			(45)
Loss on indexed debt securities			242
AT&T To Acquire Time Warner [Member] | AT&T Common [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
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
Meredith to acquire Time [Member] | Time Common [Member]
Cash paid per share exchanged | $ / shares						$ 18.50		$ 18.50
Cash proceeds received for shares exchanged			$ 16
Subsequent Event [Member]
Distribution To ZENS holders		$ 382

[1] Cash of approximately $382 million was paid to ZENS note holders in July 2018.

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Short-Term Borrowings and Long-term Debt (Details)				6 Months Ended
		Mar. 26, 2018 USD ($)	Feb. 28, 2018 USD ($)	Jun. 30, 2018 USD ($)		Dec. 31, 2017 USD ($)
Short-term Debt [Line Items]
Short-term borrowings				$ 0		$ 39,000,000
Line of Credit Facility [Abstract]
Size of credit facility				2,900,000,000		2,900,000,000
Parent Company [Member]
Line of Credit Facility [Abstract]
Size of credit facility				1,700,000,000	[1]	1,700,000,000
Temporary increased line of credit facility, maximum borrowing capacity				3,300,000,000
Houston Electric [Member]
Line of Credit Facility [Abstract]
Size of credit facility				300,000,000		300,000,000
General mortgage bonds used as collateral				118,000,000		118,000,000
CERC Corp [Member]
Short-term Debt [Line Items]
Short-term borrowings				0		39,000,000
Line of Credit Facility [Abstract]
Size of credit facility				900,000,000		900,000,000
Revolving Credit Facility [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				0		0
Revolving Credit Facility [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Long-term line of credit	[2]			0		0
Revolving Credit Facility [Member] | Houston Electric [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				0		0
Revolving Credit Facility [Member] | CERC Corp [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				$ 0		0
Line of Credit [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
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	[3]			0.521
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)				12
Line of Credit [Member] | Parent Company [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Abstract]
Basis spread on LIBOR	[4]			1.25%
Line of Credit [Member] | Houston Electric [Member]
Line of Credit Facility [Abstract]
Percentage on limitation of debt to total capitalization under covenant	[5]			65.00%
Ratio of indebtedness to net capital	[3]			0.507
Line of Credit [Member] | Houston Electric [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Abstract]
Basis spread on LIBOR	[4]			1.125%
Line of Credit [Member] | CERC Corp [Member]
Line of Credit Facility [Abstract]
Percentage on limitation of debt to total capitalization under covenant				65.00%
Ratio of indebtedness to net capital	[3]			0.378
Line of Credit [Member] | CERC Corp [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Abstract]
Basis spread on LIBOR	[4]			1.25%
Letter of Credit [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				$ 11,000,000		11,000,000
Letter of Credit [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Long-term line of credit	[2]			6,000,000		6,000,000
Letter of Credit [Member] | Houston Electric [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				4,000,000		4,000,000
Letter of Credit [Member] | CERC Corp [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				1,000,000		1,000,000
Commercial Paper [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				565,000,000		1,753,000,000
Commercial Paper [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Long-term line of credit	[2]			$ 0		$ 855,000,000
Weighted average interest rate of debt	[2]			0.00%		1.88%
Commercial Paper [Member] | Houston Electric [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				$ 0		$ 0
Commercial Paper [Member] | CERC Corp [Member]
Line of Credit Facility [Abstract]
Long-term line of credit				$ 565,000,000		$ 898,000,000
Weighted average interest rate of debt				2.37%		1.72%
General Mortgage Bonds Due 2048 [Member] | Houston Electric [Member]
Debt Instruments [Abstract]
Principal amount of debt issued			$ 400,000,000
Interest rate of debt issued			3.95%
Maturity date of debt issued			Mar. 01, 2048
Senior Notes Due 2023 [Member] | CERC Corp [Member]
Debt Instruments [Abstract]
Principal amount of debt issued		$ 300,000,000
Interest rate of debt issued		3.55%
Maturity date of debt issued		Apr. 01, 2023
Senior Notes Due 2028 [Member]
Debt Instruments [Abstract]
Principal amount of debt issued		$ 300,000,000
Interest rate of debt issued		4.00%
Maturity date of debt issued		Apr. 01, 2028
Product Financing Arrangement [Member]
Short-term Debt [Line Items]
Short-term borrowings				$ 0		$ 39,000,000
Merger Agreement with Vectren [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
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]
Line of Credit Facility [Abstract]
Percentage on limitation of debt to total capitalization under covenant amended (in hundredths)	[5],[6]			75.00%

[1] Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon the satisfaction of certain conditions described above.

[2] Pursuant to the amendment entered into in May 2018, the aggregate commitments under the CenterPoint Energy revolving credit facility will increase to $3.3 billion upon the satisfaction of certain conditions described above.

[3] As defined in the revolving credit facility agreement, excluding Securitization Bonds.

[4] Based on current credit ratings.

[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.

[6] CenterPoint Energy’s financial covenant limit will return to 65% upon the earlier of (i) June 30, 2019 or (ii) the termination of all commitments in respect of the Bridge Facility without any borrowing thereunder.

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Income Taxes (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Effective income tax rate	15.00%	36.00%	27.00%	36.00%
Federal statutory income tax rate			21.00%	35.00%
Houston Electric [Member]
Effective income tax rate	21.00%	36.00%	22.00%	36.00%
CERC Corp [Member]
Effective income tax rate	22.00%	35.00%	22.00%	37.00%

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Commitments and Contingencies (Details)	6 Months Ended
	Jun. 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 six months of 2018	$ 185,000,000
2019	264,000,000
2020	168,000,000
2021	82,000,000
2022	51,000,000
2023 and beyond	123,000,000
Minnehaha Academy Gas Explosion [Member]
Legal, Environmental and Other Matters
Contested amount of fines imposed	$ 200,000

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Earnings Per Share (CenterPoint Energy) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2018		Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net income (loss)	$ (75)		$ 135	$ 90	$ 327
Basic weighted average shares outstanding	431,523,000		430,996,000	431,378,000	430,896,000
Plus: Incremental shares from assumed conversions:
Diluted weighted average shares	431,523,000		433,797,000	434,407,000	433,697,000
Basic earnings (loss) per share
Net income (loss)	$ (0.17)		$ 0.31	$ 0.21	$ 0.76
Diluted earnings (loss) per share
Net income (loss)	$ (0.17)		$ 0.31	$ 0.21	$ 0.75
Restricted Stock [Member]
Anti-dilutive shares excluded from computation of diluted earnings (loss) per share	3,029,000
Plus: Incremental shares from assumed conversions:
Restricted stock (1)	0	[1]	2,801,000	3,029,000	2,801,000

[1] 3,029,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the three months ended June 30, 2018 as their inclusion would be anti-dilutive.

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Reportable Business Segments (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Revenues		$ 2,186	$ 2,143	$ 5,341	$ 4,878
Operating Income (Loss)		187	240	438	531
Equity in earnings from investment in Enable		58	59	127	131
Assets		22,108		22,108		$ 22,736
Total regulatory assets		2,122		2,122		2,477
Electric Transmission and Distribution [Member]
Segment Reporting Information [Line Items]
Revenues	[1]	854	752	1,605	1,391
Operating Income (Loss)		181	171	296	257
Electric Transmission and Distribution [Member] | Affiliates of NRG Energy, Inc. [Member]
Segment Reporting Information [Line Items]
Revenues		169	167	330	319
Electric Transmission and Distribution [Member] | Affiliates of Vistra Energy Corp. [Member]
Segment Reporting Information [Line Items]
Revenues		59	53	113	100
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		487	470	1,630	1,377
Operating Income (Loss)		7	42	163	210
Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		841	918	2,098	2,103
Operating Income (Loss)		15	16	(11)	51
Midstream Investments [Member]
Segment Reporting Information [Line Items]
Revenues	[2]	0	0	0	0
Operating Income (Loss)	[2]	0	0	0	0
Equity in earnings from investment in Enable		58	59	127	131
Other Operations [Member]
Segment Reporting Information [Line Items]
Revenues		4	3	8	7
Operating Income (Loss)		(16)	11	(10)	13
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues		(27)	(20)	(65)	(40)
Assets		(841)		(841)		(654)
Intersegment Eliminations [Member] | Electric Transmission and Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		0	0	0	0
Intersegment Eliminations [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		(8)	(7)	(18)	(16)
Intersegment Eliminations [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		(19)	(13)	(47)	(24)
Intersegment Eliminations [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Revenues	[2]	0	0	0	0
Intersegment Eliminations [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Revenues		0	0	0	0
Operating Segments [Member] | Electric Transmission and Distribution [Member]
Segment Reporting Information [Line Items]
Assets		10,430		10,430		10,292
Operating Segments [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Assets		6,501		6,501		6,608
Operating Segments [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Assets		1,256		1,256		1,521
Operating Segments [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Assets		2,451		2,451		2,472
Operating Segments [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Assets	[3]	2,311		2,311		2,497
Pension and Other Postretirement Plans Costs [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Total regulatory assets		577		577		600
CERC Corp [Member]
Segment Reporting Information [Line Items]
Revenues		1,328	1,387	3,728	3,480
Operating Income (Loss)		22	59	153	258
Equity in earnings from investment in Enable		58	59	127	131
Assets		9,642		9,642		10,112
Total regulatory assets		228		228		311
CERC Corp [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		487	470	1,630	1,377
Operating Income (Loss)		7	42	163	210
CERC Corp [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		841	918	2,098	2,103
Operating Income (Loss)		15	16	(11)	51
CERC Corp [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Revenues	[2]	0	0	0	0
Operating Income (Loss)	[2]	0	0	0	0
CERC Corp [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Revenues		0	(1)	0	0
Operating Income (Loss)		0	1	1	(3)
CERC Corp [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues		(27)	(20)	(65)	(40)
Assets		(655)		(655)		(559)
CERC Corp [Member] | Intersegment Eliminations [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		(8)	(7)	(18)	(16)
CERC Corp [Member] | Intersegment Eliminations [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		(19)	(13)	(47)	(24)
CERC Corp [Member] | Intersegment Eliminations [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Revenues	[2]	0	0	0	0
CERC Corp [Member] | Intersegment Eliminations [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Revenues		0	$ 0	0	$ 0
CERC Corp [Member] | Operating Segments [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Assets		6,501		6,501		6,608
CERC Corp [Member] | Operating Segments [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Assets		1,256		1,256		1,521
CERC Corp [Member] | Operating Segments [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Assets		2,451		2,451		2,472
CERC Corp [Member] | Operating Segments [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Assets		$ 89		$ 89		$ 70

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

[2] CenterPoint Energy’s and CERC’s Midstream Investments’ equity earnings, net are as follows: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in millions)Enable $58 $59 $127 $131

[3] Includes pension and other postemployment-related regulatory assets of $577 million and $600 million, respectively, as of June 30, 2018 and December 31, 2017.

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Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Interest, net of capitalized interest	$ 167	$ 182
Income taxes, net	88	11
Accounts payable related to capital expenditures	133	106
Cash and cash equivalents	328		$ 260
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	366	280	296	$ 381
Prepaid expenses and other current assets [Member]
Restricted cash	37		35
Other [Member]
Restricted cash	1		1
Houston Electric [Member]
Interest, net of capitalized interest	90	94
Income taxes, net	120	76
Accounts payable related to capital expenditures	75	75
Cash and cash equivalents	253		238
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	291	277	274	381
Houston Electric [Member] | Prepaid expenses and other current assets [Member]
Restricted cash	37		35
Houston Electric [Member] | Other [Member]
Restricted cash	1		1
CERC Corp [Member]
Interest, net of capitalized interest	50	56
Income taxes, net	3	3
Accounts payable related to capital expenditures	69	44
Cash and cash equivalents	$ 1	$ 1	$ 12	$ 1

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Related Party Transactions (Houston Electric and CERC) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Houston Electric [Member]
Related Party Transaction [Line Items]
Dividends paid		$ 31	$ 10	$ 63	$ 42
Houston Electric [Member] | Operation and maintenance expense [Member]
Related Party Transaction [Line Items]
Net affiliate service charges (billings)		(3)	(4)	(5)	(5)
Houston Electric [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]
Related Party Transaction [Line Items]
Corporate service charges		47	44	91	86
CERC Corp [Member]
Related Party Transaction [Line Items]
Dividends paid		125	140	211	248
CERC Corp [Member] | Operation and maintenance expense [Member]
Related Party Transaction [Line Items]
Net affiliate service charges (billings)		3	4	5	5
CERC Corp [Member] | CenterPoint Energy [Member] | Operation and maintenance expense [Member]
Related Party Transaction [Line Items]
Corporate service charges		$ 35	$ 32	$ 69	$ 63
Investments [Member] | Houston Electric [Member]
Related Party Transaction [Line Items]
Weighted average interest rate		2.00%		2.00%		1.90%
Investments [Member] | CERC Corp [Member]
Related Party Transaction [Line Items]
Weighted average interest rate		0.00%		0.00%		1.90%
Accounts and notes receivable (payable) - affiliate companies [Member] | Houston Electric [Member]
Related Party Transaction [Line Items]
Money pool investments (borrowings) (1)	[1]	$ 26		$ 26		$ (60)
Accounts and notes receivable (payable) - affiliate companies [Member] | CERC Corp [Member]
Related Party Transaction [Line Items]
Money pool investments (borrowings) (1)	[1]	$ 0		$ 0		$ (570)

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

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Subsequent Events (CenterPoint Energy and CERC) (Details) - USD ($) $ / shares in Units, $ in Millions			3 Months Ended		6 Months Ended
	Aug. 01, 2018	Jul. 26, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Subsequent Event [Line Items]
Quarterly cash dividend/distribution declared per share			$ 0.2775	$ 0.2675	$ 0.2775	$ 0.5350
Subsequent Event [Member]
Subsequent Event [Line Items]
Dividends payable, date declared		Jul. 26, 2018
Quarterly cash dividend/distribution declared per share		$ 0.2775
Dividends payable, date to be paid		Sep. 13, 2018
Dividends payable, date of record		Aug. 16, 2018
Subsequent Event [Member] | Enable Midstream Partners [Member] | Common Units [Member]
Subsequent Event [Line Items]
Dividends payable, date declared	Aug. 01, 2018
Quarterly cash dividend/distribution declared per share	$ 0.318
Expected cash distribution from equity method investment	$ 74
Subsequent Event [Member] | Enable Midstream Partners [Member] | Series A Preferred Units [Member]
Subsequent Event [Line Items]
Dividends payable, date declared	Aug. 01, 2018
Preferred stock dividends declared per share	$ 0.625
Expected cash distribution from cost method investment	$ 9