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, 2016

OR

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

Commission file number 1-31447

_____________________________________

CenterPoint Energy, Inc.

(Exact name of registrant as specified in its charter)

Texas	74-0694415
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
1111 Louisiana
Houston, Texas 77002	(713) 207-1111
(Address and zip code of principal executive offices)	(Registrant’s telephone number, including area code)

_____________________________________

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. Yes þ  No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes þ  No o

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

Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o
		(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o  No þ

As of July 29, 2016, CenterPoint Energy, Inc. had 430,681,744 shares of common stock outstanding, excluding 166 shares held as treasury stock.

CENTERPOINT ENERGY, INC.

QUARTERLY REPORT ON FORM 10-Q

FOR THE QUARTER ENDED JUNE 30, 2016

TABLE OF CONTENTS

PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	Condensed Statements of Consolidated Income
	Three and Six Months Ended June 30, 2016 and 2015 (unaudited)	1
	Condensed Statements of Consolidated Comprehensive Income
	Three and Six Months Ended June 30, 2016 and 2015 (unaudited)	2
	Condensed Consolidated Balance Sheets
	June 30, 2016 and December 31, 2015 (unaudited)	3
	Condensed Statements of Consolidated Cash Flows
	Six Months Ended June 30, 2016 and 2015 (unaudited)	5
	Notes to Unaudited Condensed Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	42
Item 4.	Controls and Procedures	43
PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	43
Item 1A.	Risk Factors	43
Item 5.	Other Information	43
Item 6.	Exhibits	44

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`

GLOSSARY
AOL	AOL Inc.
APSC	Arkansas Public Service Commission
ArcLight	ArcLight Capital Partners, LLC
ASU	Accounting Standards Update
Bcf	Billion cubic feet
BDA	Billing Determinant Adjustment
Bond Companies	Transition and system restoration bond companies
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
CECL	Current expected credit losses
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.
Charter	Charter Communications, Inc.
Charter Common	Charter common stock
Choice customers	Residential and small commercial customers who have the option to choose a natural gas supplier as governed by the local distribution company’s filed transportation tariffs
CIP	Conservation Improvement Program
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
Dodd-Frank	Dodd-Frank Wall Street Reform and Consumer Protection Act
EECRF	Energy Efficiency Cost Recovery Factor
Enable	Enable Midstream Partners, LP
ERCOT	Electric Reliability Council of Texas
FASB	Financial Accounting Standards Board
Fitch	Fitch, Inc.
Form 10-Q	Quarterly Report on Form 10-Q
GenOn	GenOn Energy, Inc.
GRIP	Gas Reliability Infrastructure Program
GWh	Gigawatt-hours
Houston Electric	CenterPoint Energy Houston Electric, LLC and its subsidiaries
IBEW	International Brotherhood of Electrical Workers
Interim Condensed Financial Statements	Condensed consolidated interim financial statements and notes
IRS	Internal Revenue Service
LIBOR	London Interbank Offered Rate
LPSC	Louisiana Public Service Commission
MGPs	Manufactured gas plants
Moody’s	Moody’s Investors Service, Inc.
MPSC	Mississippi Public Service Commission
MPUC	Minnesota Public Utilities Commission
NAV	Net asset value
NECA	National Electrical Contractors Association
NGD	Natural gas distribution business

ii

GLOSSARY (cont.)
NGLs	Natural gas liquids
NRG	NRG Energy, Inc.
OGE	OGE Energy Corp.
PBRC	Performance Based Rate Change
PHMSA	Pipeline and Hazardous Materials Safety Administration
Private Placement	An agreement with Enable to purchase an aggregate of 14,520,000 Series A Preferred Units
PRPs	Potentially responsible parties
Reliant Energy	Reliant Energy, Incorporated
REP	Retail electric provider
ROE	Return on equity
ROR	Return on revenue
RRA	Rate Regulation Adjustment
RRI	Reliant Resources, Inc.
RSP	Rate Stabilization Plan
SEC	Securities and Exchange Commission
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
S&P	Standard & Poor’s Ratings Services, a division of The McGraw-Hill Companies
TCOS	Transmission Cost of Service
TDU	Transmission and distribution utility
Texas Utility Commission	Public Utility Commission of Texas
Time Common	Time Inc. 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
TWC	Time Warner Cable Inc.
TWC Common	TWC common stock
TW Securities	Charter Common, Time Common and TW Common
Verizon	Verizon Communications, Inc.
VIE	Variable interest entity
ZENS	2.0% Zero-Premium Exchangeable Subordinated Notes due 2029
2015 Form 10-K	Annual Report on Form 10-K for the year ended December 31, 2015

iii

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

From time to time we make statements concerning our 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 our forward-looking statements by the words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “objective,” “plan,” “potential,” “predict,” “projection,” “should,” “will” or other similar words.

We have based our forward-looking statements on our management’s beliefs and assumptions based on information reasonably available to our management at the time the statements are made. We caution you that assumptions, beliefs, expectations, intentions and projections about future events may and often do vary materially from actual results. Therefore, we cannot assure you that actual results will not differ materially from those expressed or implied by our forward-looking statements.

The following are some of the factors that could cause actual results to differ from those expressed or implied by our forward-looking statements:

• the performance of Enable, the amount of cash distributions we receive from Enable, Enable’s ability to redeem the Series A Preferred Units in certain circumstances and the value of our 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;

• 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, health care reform, financial reform, tax legislation and actions regarding the rates charged by our regulated businesses;

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

• industrial, commercial and residential growth in our service territories and changes in market demand, including the effects of energy efficiency measures and demographic patterns;

• 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;

• our 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;

• 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;

iv

• any direct or indirect effects on our 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;

• actions by credit rating agencies;

• the sufficiency of our insurance coverage, including availability, cost, coverage and terms;

• the investment performance of our 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 interest rates or 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;

• effectiveness of our risk management activities;

• timely and appropriate regulatory actions allowing securitization or other recovery of costs associated with any future hurricanes or natural disasters;

• our potential business strategies and strategic initiatives, including restructurings, joint ventures and acquisitions or dispositions of assets or businesses, which we cannot assure you will be completed or will have the anticipated benefits to us;

• acquisition and merger activities involving us or our competitors;

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

• the ability of GenOn (formerly known as RRI Energy, Inc., Reliant Energy and RRI), a wholly-owned subsidiary of NRG, and its subsidiaries to satisfy their obligations to us, including indemnity obligations, or obligations in connection with the contractual arrangements pursuant to which we are their guarantor;

• the outcome of litigation;

• the ability of REPs, including REP affiliates of NRG and Energy Future Holdings Corp., to satisfy their obligations to us and our subsidiaries;

• 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 we discuss in “Risk Factors” in Item 1A of Part I of our 2015 Form 10-K, which is incorporated herein by reference, and other reports we 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.

v

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,
	2016			2015			2016			2015
Revenues	$	1,574		$	1,532		$	3,558		$	3,965
Expenses:
Natural gas	496			529			1,348			1,883
Operation and maintenance	513			488			1,034			986
Depreciation and amortization	289			239			549			456
Taxes other than income taxes	94			90			195			198
Total	1,392			1,346			3,126			3,523
Operating Income	182			186			432			442
Other Income (Expense):
Gain on marketable securities	20			79			110			62
Loss on indexed debt securities	(130		)	(91		)	(186		)	(67		)
Interest and other finance charges	(86		)	(89		)	(173		)	(178		)
Interest on securitization bonds	(23		)	(27		)	(47		)	(55		)
Equity in earnings of unconsolidated affiliate, net	31			43			91			95
Other, net	14			13			21			24
Total	(174		)	(72		)	(184		)	(119		)
Income Before Income Taxes	8			114			248			323
Income tax expense	10			37			96			115
Net Income (Loss)	$	(2	)	$	77		$	152		$	208
Basic Earnings (Loss) Per Share	$	(0.01	)	$	0.18		$	0.35		$	0.48
Diluted Earnings (Loss) Per Share	$	(0.01	)	$	0.18		$	0.35		$	0.48
Dividends Declared Per Share	$	0.2575		$	0.2475		$	0.5150		$	0.4950
Weighted Average Shares Outstanding, Basic	431			430			431			430
Weighted Average Shares Outstanding, Diluted	431			432			433			432

See Notes to Interim 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,
	2016			2015		2016			2015
Net income (loss)	$	(2	)	$	77	$	152		$	208
Other comprehensive income (loss):
Adjustment related to pension and other postretirement plans (net of tax of $2, $-0-, $1 and $2)	(1		)	2		—			4
Net deferred loss from cash flow hedges (net of tax of $1, $-0-, $1, $-0-)	(1		)	—		(1		)	—
Total	(2		)	2		(1		)	4
Comprehensive income (loss)	$	(4	)	$	79	$	151		$	212

See Notes to Interim Condensed Consolidated Financial Statements

2

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Millions)

(Unaudited)

ASSETS

	June 30, 2016		December 31, 2015
Current Assets:
Cash and cash equivalents ($246 and $264 related to VIEs, respectively)	$	271	$	264
Investment in marketable securities	737		805
Accounts receivable ($92 and $64 related to VIEs, respectively), less bad debt reserve of $24 and $20, respectively	605		593
Accrued unbilled revenues	178		279
Natural gas inventory	96		168
Materials and supplies	187		179
Non-trading derivative assets	47		89
Taxes receivable	16		172
Prepaid expenses and other current assets ($37 and $35 related to VIEs, respectively)	135		140
Total current assets	2,272		2,689
Property, Plant and Equipment:
Property, plant and equipment	17,218		16,650
Less: accumulated depreciation and amortization	5,320		5,113
Property, plant and equipment, net	11,898		11,537
Other Assets:
Goodwill	861		840
Regulatory assets ($2,156 and $2,373 related to VIEs, respectively)	2,913		3,129
Notes receivable – unconsolidated affiliate	—		363
Non-trading derivative assets	22		36
Investment in unconsolidated affiliate	2,536		2,594
Preferred units – unconsolidated affiliate	363		—
Other	147		102
Total other assets	6,842		7,064
Total Assets	$	21,012	$	21,290

See Notes to Interim 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, 2016			December 31, 2015
Current Liabilities:
Short-term borrowings	$	17		$	40
Current portion of VIE securitization bonds long-term debt	402			391
Indexed debt	111			145
Current portion of other long-term debt	250			328
Indexed debt securities derivative	490			442
Accounts payable	407			483
Taxes accrued	92			158
Interest accrued	119			117
Non-trading derivative liabilities	19			11
Other	334			343
Total current liabilities	2,241			2,458
Other Liabilities:
Deferred income taxes, net	5,121			5,047
Non-trading derivative liabilities	6			5
Benefit obligations	904			904
Regulatory liabilities	1,284			1,276
Other	279			273
Total other liabilities	7,594			7,505
Long-term Debt:
VIE securitization bonds	2,059			2,276
Other long-term debt	5,721			5,590
Total long-term debt	7,780			7,866
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock (430,681,491 shares and 430,262,703 shares outstanding, respectively)	4			4
Additional paid-in capital	4,186			4,180
Accumulated deficit	(726		)	(657		)
Accumulated other comprehensive loss	(67		)	(66		)
Total shareholders’ equity	3,397			3,461
Total Liabilities and Shareholders’ Equity	$	21,012		$	21,290

See Notes to Interim Condensed Consolidated Financial Statements

4

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(In Millions)

(Unaudited)

	Six Months Ended June 30,
	2016			2015
Cash Flows from Operating Activities:
Net income	$	152		$	208
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	549			456
Amortization of deferred financing costs	13			14
Deferred income taxes	69			4
Unrealized gain on marketable securities	(110		)	(62		)
Loss on indexed debt securities	186			67
Write-down of natural gas inventory	1			2
Equity in (earnings) losses of unconsolidated affiliate, net of distributions	(91		)	50
Pension contributions	(5		)	(25		)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	147			367
Inventory	63			103
Taxes receivable	156			152
Accounts payable	(109		)	(327		)
Fuel cost recovery	(17		)	86
Non-trading derivatives, net	22			2
Margin deposits, net	65			25
Interest and taxes accrued	(64		)	(66		)
Net regulatory assets and liabilities	(21		)	78
Other current assets	4			23
Other current liabilities	21			(38		)
Other liabilities	17			(3		)
Other, net	10			6
Net cash provided by operating activities	1,058			1,122
Cash Flows from Investing Activities:
Capital expenditures	(682		)	(712		)
Acquisitions, net of cash acquired	(98		)	—
Decrease in notes receivable – unconsolidated affiliate	363			—
Investment in preferred units – unconsolidated affiliate	(363		)	—
Distributions from unconsolidated affiliate in excess of cumulative earnings	149			—
Decrease (increase) in restricted cash of Bond Companies	(2		)	13
Proceeds from sale of marketable securities	178			32
Other, net	(12		)	(4		)
Net cash used in investing activities	(467		)	(671		)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(23		)	(29		)
Proceeds of commercial paper, net	278			137
Proceeds from long-term debt	300			—
Payments of long-term debt	(735		)	(400		)
Debt issuance costs	(7		)	—
Payment of common stock dividends	(221		)	(213		)
Distribution to ZENS note holders	(178		)	—
Other, net	2			1
Net cash used in financing activities	(584		)	(504		)
Net Increase (Decrease) in Cash and Cash Equivalents	7			(53		)
Cash and Cash Equivalents at Beginning of Period	264			298
Cash and Cash Equivalents at End of Period	$	271		$	245
Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	200		$	209
Income tax refunds, net	(126		)	(38		)
Non-cash transactions:
Accounts payable related to capital expenditures	79			81

See Notes to Interim Condensed Consolidated Financial Statements

5

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1) Background and Basis of Presentation

General. Included in this Form 10-Q are the Interim Condensed Financial Statements of CenterPoint Energy. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the 2015 Form 10-K.

Background. CenterPoint Energy, Inc. is a public utility holding company. CenterPoint Energy’s operating subsidiaries own and operate electric transmission and distribution facilities and natural gas distribution facilities, and both CenterPoint Energy and its operating subsidiaries own interests in Enable as described in Note 8. As of June 30, 2016, CenterPoint Energy’s indirect, wholly-owned subsidiaries included:

• Houston Electric, which engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston; and

• CERC Corp. (together with its subsidiaries), which owns and operates natural gas distribution systems. A wholly-owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and natural gas utilities. As of June 30, 2016, CERC Corp. also owned approximately 55.4% of the limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

As of June 30, 2016, CenterPoint Energy had VIEs consisting of Bond Companies, which it consolidates. 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 have no recourse to any assets or revenues of 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.

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.

CenterPoint Energy’s 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 CenterPoint Energy’s 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.

For a description of CenterPoint Energy’s reportable business segments, see Note 16.

(2) New Accounting Pronouncements

In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (ASU 2015-02). ASU 2015-02 changes the analysis that reporting organizations must perform to evaluate whether they should consolidate certain legal entities, such as limited partnerships. The changes include, among others, modification of the evaluation of whether limited partnerships and similar legal entities are VIEs or voting interest entities and elimination of the presumption that a general partner should consolidate a limited partnership. ASU 2015-02 does not amend the related party guidance for situations in which power is shared between two or more entities that hold interests in a VIE. CenterPoint Energy adopted ASU 2015-02 on January 1, 2016, which CenterPoint Energy determined did not have a material impact on its financial position, results of operations, cash flows and disclosures.

In April 2015, the FASB issued ASU No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Cost (ASU 2015-03). ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by ASU 2015-03. CenterPoint Energy adopted ASU 2015-03 retrospectively on January 1, 2016, which resulted in a reduction of other long-term assets, indexed debt

6

and total long-term debt on its Condensed Consolidated Balance Sheets. CenterPoint Energy had debt issuance costs, excluding amounts related to credit facility arrangements, of $43 million and $44 million as of June 30, 2016 and December 31, 2015, respectively.

In May 2015, the FASB issued ASU No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent) (ASU 2015-07). ASU 2015-07 removes the requirement to categorize within the fair value hierarchy investments for which fair values are measured at NAV using the practical expedient. Entities will be required to disclose the fair value of investments measured using the NAV practical expedient so that financial statement users can reconcile amounts reported in the fair value hierarchy table to amounts reported on the balance sheet. CenterPoint Energy adopted ASU 2015-07 on January 1, 2016, which will have an impact on its employee benefit plan disclosures, beginning with its annual report on Form 10-K for the year ended December 31, 2016. This standard did not have an impact on CenterPoint Energy’s financial position, results of operations or cash flows.

In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments (ASU 2015-16). ASU 2015-16 eliminates the requirement for an acquirer in a business combination to account for measurement-period adjustments retrospectively. Instead, an acquirer would recognize a measurement-period adjustment during the period in which the amount of the adjustment is determined. CenterPoint Energy adopted ASU 2015-16 on January 1, 2016, which did not have an impact on its financial position, results of operations or cash flows.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities (ASU 2016-01). ASU 2016-01 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. ASU 2016-01 also changes certain disclosure requirements and other aspects related to recognition and measurement of financial assets and financial liabilities. ASU 2016-01 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). 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. ASU 2016-02 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018, with early adoption permitted. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

In March 2016, the FASB issued ASU No. 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novation on Existing Hedge Accounting Relationships (ASU 2016-05). ASU 2016-05 clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument in an existing hedging relationship would not, in and of itself, be considered a termination of the derivative instrument or a change in a critical term of the hedging relationship. This clarification applies to both cash flow and fair value hedging relationships. CenterPoint Energy adopted ASU 2016-05 prospectively in the first quarter of 2016, which did not have an impact on its financial position, results of operations, cash flows and disclosures.

In March, April, and May 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (ASU 2016-08), ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing (ASU 2016-10), and ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients (ASU 2016-12), respectively. ASU 2016-08, ASU 2016-10, and ASU 2016-12 clarify certain aspects of ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (ASU 2014-09), which supersedes most current revenue recognition guidance. CenterPoint Energy is currently evaluating the impact that ASU 2016-08, ASU 2016-10, ASU 2016-12, and ASU 2014-09 will have on its financial position, results of operations, cash flows and disclosures and expects to adopt these ASUs on January 1, 2018.

In March 2016, the FASB issued ASU No. 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (ASU 2016-09). ASU 2016-09 will change the accounting for certain aspects of share-based payments to employees, including the recognition of income tax effects of vested or settled awards in the income statement, instead of within additional paid-in capital. It will also increase the amount an employer can withhold to cover income taxes on awards and still qualify for the exception to liability classification for shares used to satisfy the employer’s statutory income tax withholding obligations. ASU 2016-09 will allow companies to elect between two different methods to account for forfeitures of share-based payments. ASU 2016-09 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

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In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (ASU 2016-13). ASU 2016-13 requires a new model called the CECL model to estimate credit losses for financial assets subject to credit losses and measured at amortized cost and certain off-balance sheet credit exposures. This includes loans, held-to-maturity debt securities, loan commitments, financial guarantees, and net investments in leases, as well as reinsurance and trade receivables. Upon initial recognition of the exposure, the CECL model requires an entity to estimate the credit losses expected over the life of an exposure based on historical information, current information and reasonable and supportable forecasts, including estimates of prepayments. The update also amends the other-than-temporary impairment model for debt securities classified as available-for-sale. ASU 2016-13 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted beginning after December 15, 2018. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

Management believes that other recently issued standards, which are not yet effective, will not have a material impact on CenterPoint Energy’s consolidated financial position, results of operations or cash flows upon adoption.

(3) Acquisition

On April 1, 2016,CES, an indirect, wholly-owned subsidiary of CenterPoint Energy, closed the previously announced agreement to acquire the retail energy services business and natural gas wholesale assets of Continuum for $98 million. The purchase price was allocated to identifiable assets acquired and liabilities assumed based on their estimated fair values on the acquisition date. As additional information becomes available, the preliminary purchase price allocation may be revised during the remainder of the measurement period (which will not exceed 12 months from the acquisition date). Any such revisions or changes are not expected to be material.

The following table summarizes the total preliminary purchase price allocation and the fair value amounts recognized for the assets acquired and liabilities assumed related to the acquisition:

	(in millions)
Total purchase price consideration	$	98
Receivables	$	75
Derivative assets	38
Property and equipment	1
Identifiable intangibles	36
Total assets acquired	150
Accounts payable	49
Derivative liabilities	24
Total liabilities assumed	73
Identifiable net assets acquired	77
Goodwill	21
Net assets acquired	$	98

The goodwill of $21 million resulting from the acquisition reflects the excess of the purchase price over the fair value of the net identifiable assets acquired. The goodwill recorded as part of the acquisition primarily reflects the value of the complementary operational and geographic footprints provided, along with the scale, geographic reach and expanded capabilities.

Identifiable intangible assets were recorded at estimated fair value as determined by management based on available information, which includes a preliminary valuation prepared by an independent third party. The significant assumptions used in arriving at the estimated identifiable intangible asset values included management’s estimates of future cash flows, the discount rate which is based on the weighted average cost of capital for comparable publicly traded guideline companies and projected customer attrition rates. The useful lives for the identifiable intangible assets were determined using methods that approximate the pattern of economic benefit provided by the utilization of the assets.

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

	Estimate Fair Value		Estimate Useful Life
	(in millions)		(in years)
Customer relationships	$	32	15
Covenants not to compete	4		4
Total identifiable intangibles	$	36

Amortization expense related to the above identifiable intangible assets was $1 million for the three and six months ended June 30, 2016 and is expected to be $2 million for 2016.

Revenues of $108 million and operating income of less than $1 million attributable to the acquisition are included in CenterPoint Energy’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2016.

As Continuum was a non-public company that did not prepare interim financial information, the historical financial information for the businesses and assets acquired was impracticable to obtain. As a result, pro forma results of the acquired businesses and assets are not presented.

(4) Employee Benefit Plans

CenterPoint Energy’s net periodic cost includes the following components relating to pension and postretirement benefits:

	Three Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	9		$	—		$	10		$	—
Interest cost	24			5			23			5
Expected return on plan assets	(25		)	(1		)	(30		)	(1		)
Amortization of prior service cost (credit)	2			(1		)	2			(1		)
Amortization of net loss	16			—			15			1
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	26		$	—		$	20		$	4
	Six Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	18		$	1		$	20		$	1
Interest cost	47			9			46			10
Expected return on plan assets	(50		)	(3		)	(60		)	(3		)
Amortization of prior service cost (credit)	4			(1		)	5			(1		)
Amortization of net loss	32			—			29			2
Settlement cost (2)	—			—			9			—
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	51		$	3		$	49		$	9

(1) Net periodic cost in these tables is before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes.  

(2) A one-time, non-cash settlement charge is required when lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of net periodic cost for that year.  Due to the amount of lump sum payment distributions from the non-qualified pension plan during the six months ended

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June 30, 2015, CenterPoint Energy recognized a non-cash settlement charge of $9 million.  This charge is an acceleration of costs that would otherwise be recognized in future periods. 

(3) A curtailment gain or loss is required when the expected future services of a significant number of current employees are reduced or eliminated for the accrual of benefits. In May 2016, Houston Electric entered into a renegotiated collective bargaining agreement with the IBEW Local Union 66 that provides that for Houston Electric union employees covered under the agreement who retire on or after January 1, 2017, retiree medical and prescription drug coverage will be provided exclusively through the NECA/IBEW Family Medical Care Plan in exchange for the payment of monthly premiums as determined under the agreement. As a result, the accrued postretirement benefits related to such future Houston Electric union retirees were eliminated. Houston Electric recognized a curtailment gain of $3 million as an accelerated recognition of the prior service credit that would otherwise be recognized in future periods.

CenterPoint Energy’s changes in accumulated comprehensive loss related to defined benefit and postretirement plans are as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	Pension and Postretirement Plans						Pension and Postretirement Plans
	(in millions)
Beginning Balance	$	(64	)	$	(83	)	$	(65	)	$	(85	)
Other comprehensive income (loss) before reclassifications (1)	(4		)	—			(4		)	—
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	1			2			3			6
Tax benefit (expense)	2			—			1			(2		)
Net current period other comprehensive income (loss)	(1		)	2			—			4
Ending Balance	$	(65	)	$	(81	)	$	(65	)	$	(81	)

(1) Total other comprehensive income (loss) related to the remeasurement of the postretirement plan.

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

CenterPoint Energy expects to contribute a total of approximately $8 million to its pension plans in 2016, of which approximately $2 million and $5 million were contributed during the three and six months ended June 30, 2016, respectively.

CenterPoint Energy expects to contribute a total of approximately $16 million to its postretirement benefit plan in 2016, of which approximately $4 million and $8 million were contributed during the three and six months ended June 30, 2016, respectively.

(5) Regulatory Accounting

As of June 30, 2016, Houston Electric has not recognized an allowed equity return of $363 million because such return will be recognized as it is recovered in rates. During the three months ended June 30, 2016 and 2015, Houston Electric recognized approximately $17 million and $12 million, respectively, of the allowed equity return not previously recognized. During the six months ended June 30, 2016 and 2015, Houston Electric recognized approximately $30 million and $21 million, respectively, of the allowed equity return not previously recognized.

(6) Derivative Instruments

CenterPoint Energy is exposed to various market risks. These risks arise from transactions entered into in the normal course of business.  CenterPoint Energy utilizes derivative instruments such as physical forward contracts, swaps and options to mitigate the impact of changes in commodity prices and weather on its operating results and cash flows. Such derivatives are recognized in CenterPoint Energy’s Condensed Consolidated Balance Sheets at their fair value unless CenterPoint Energy elects the normal purchase and sales exemption for qualified physical transactions. A derivative may be designated as a normal purchase or sale if the intent is to physically receive or deliver the product for use or sale in the normal course of business.

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CenterPoint Energy has a Risk Oversight Committee composed of corporate and business segment officers that oversees commodity price, weather and credit risk activities, including CenterPoint Energy’s marketing, risk management services and hedging activities. The committee’s duties are to establish CenterPoint Energy’s commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions and ensure compliance with CenterPoint Energy’s risk management policies, procedures and limits established by CenterPoint Energy’s board of directors.

CenterPoint Energy’s 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 enters into certain derivative instruments to manage physical commodity price risk and does not engage in proprietary or speculative commodity trading.  These financial instruments do not qualify or are not designated as cash flow or fair value hedges.

Weather Hedges. CenterPoint Energy has 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 CenterPoint Energy’s other jurisdictions. As a result, fluctuations from normal weather may have a positive or negative effect on NGD’s results in Texas and on Houston Electric’s results in its service territory.

CenterPoint Energy has historically entered into heating-degree day swaps for certain NGD jurisdictions to mitigate the effect of fluctuations from normal weather on its results of operations and cash flows for the winter heating season, which contained a bilateral dollar cap of $16 million in 2014–2015. However, NGD did not enter into heating-degree day swaps for the 2015–2016 winter season as a result of NGD’s Minnesota division implementing a full decoupling pilot in July 2015. CenterPoint Energy also entered into weather hedges for the Houston Electric service territory, which contained a bilateral dollar cap of $8 million for the 2014–2015 winter season and a bilateral dollar cap of $7 million for the 2015–2016 winter season. The swaps are based on 10-year normal weather. During the three months ended June 30, 2016 and 2015, CenterPoint Energy recognized gains of $-0- and $1 million, respectively, related to these swaps. During the six months ended June 30, 2016 and 2015, CenterPoint Energy recognized gains of $3 million and losses of $9 million, respectively, related to these swaps. Weather hedge gains and losses are included in revenues in the Condensed Statements of Consolidated Income.

Hedging of Interest Expense for Future Debt Issuances. In April 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $150 million. These agreements were executed to hedge, in part, volatility in the 5-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows related to interest payments of Houston Electric’s $300 million issuance of fixed rate debt in May 2016. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the ineffective portion of unrealized gains and losses associated with the agreements was recorded in income and was immaterial.

In June and July 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $300 million. These agreements were executed to hedge, in part, volatility in the 10-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows relating to interest payments on a forecasted issuance of fixed rate debt in 2016.  These forward interest rate agreements were designated as cash flow hedges.  As of June 30, 2016, a $2 million current non-trading derivative liability was recorded on the Condensed Consolidated Balance Sheets related to these agreements. Accordingly, the effective portion of unrealized gains and losses associated with the agreements would be recorded as a component of accumulated other comprehensive income and the ineffective portion would be recorded in income.

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(b) Derivative Fair Values and Income Statement Impacts

The following tables present information about CenterPoint Energy’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CenterPoint Energy’s Derivative Assets and Liabilities as of June 30, 2016 and December 31, 2015, while the last table provides a breakdown of the related income statement impacts for the three and six months ended June 30, 2016 and 2015.

Fair Value of Derivative Instruments
	June 30, 2016
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	49	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	28		6
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	28		45
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	—		6
Indexed debt securities derivative	Current Liabilities	—		490
Total		$	105	$	549

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,085 Bcf or a net 6 Bcf short position.  Of the net short position, basis swaps constitute a net 136 Bcf long position.

(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 $46 million asset, excluding a $2 million interest rate derivative liability, as shown on CenterPoint Energy’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, offset by collateral netting of less than $1 million.

(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
	June 30, 2016
	Gross AmountsRecognized (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	$	77		$	(30	)	$	47
Other Assets: Non-trading derivative assets	28			(6		)	22
Current Liabilities: Non-trading derivative liabilities	(47		)	30			(17		)
Other Liabilities: Non-trading derivative liabilities	(12		)	6			(6		)
Total	$	46		$	—		$	46

(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.

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Fair Value of Derivative Instruments
	December 31, 2015
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	90	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	36		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	10		60
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	4		25
Indexed debt securities derivative	Current Liabilities	—		442
Total		$	140	$	529

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 767 Bcf or a net 112 Bcf long position.  Of the net long position, basis swaps constitute 133 Bcf.

(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 $109 million asset as shown on CenterPoint Energy’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, offset by collateral netting of $56 million.

(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
	December 31, 2015
	Gross AmountsRecognized (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	$	100		$	(11	)	$	89
Other Assets: Non-trading derivative assets	40			(4		)	36
Current Liabilities: Non-trading derivative liabilities	(62		)	51			(11		)
Other Liabilities: Non-trading derivative liabilities	(25		)	20			(5		)
Total	$	53		$	56		$	109

(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.

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Realized and unrealized gains and losses on natural gas derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for retail sales derivative contracts and as natural gas expense for financial natural gas derivatives and non-retail related physical 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.

Income Statement Impact of Derivative Activity
		Three Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(50	)	$	7
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	59			1
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(130		)	(91		)
Total		$	(121	)	$	(83	)

Income Statement Impact of Derivative Activity
		Six Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(30	)	$	49
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	48			(42		)
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(186		)	(67		)
Total		$	(168	)	$	(60	)

(c) Credit Risk Contingent Features

CenterPoint Energy enters into financial derivative contracts containing material adverse change provisions.  These provisions could require CenterPoint Energy to post additional collateral if the S&P or Moody’s credit ratings of CenterPoint Energy, Inc. or its subsidiaries are downgraded.  The total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position as of both June 30, 2016 and December 31, 2015 was $3 million.  CenterPoint Energy posted no assets as collateral towards derivative instruments that contain credit risk contingent features as of either June 30, 2016 or December 31, 2015.  If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered as of both June 30, 2016 and December 31, 2015, $2 million of additional assets would be required to be posted as collateral.

(7) Fair Value Measurements

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

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

Level 2: Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, 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 CenterPoint Energy’s 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 CenterPoint Energy’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. CenterPoint Energy develops these inputs based on the best information available, including CenterPoint Energy’s own data. A market approach is utilized to value CenterPoint Energy’s Level 3 assets or liabilities. As of June 30, 2016, CenterPoint Energy’s Level 3 assets and liabilities are comprised of physical forward contracts and options. Level 3 physical forward contracts are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.92 to $3.72 per one million British thermal units) as an unobservable input. Level 3 options are valued through Black-Scholes (including forward start) option models which

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include option volatilities (ranging from 0% to 85%) as an unobservable input.  CenterPoint Energy’s Level 3 derivative assets and liabilities consist of both long and short positions (forwards and options) and their fair value is sensitive to forward prices and volatilities. If forward prices decrease, CenterPoint Energy’s long forwards lose value whereas its short forwards gain in value.  If volatility decreases, CenterPoint Energy’s long options lose value whereas its short options gain in value.

CenterPoint Energy determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period.  For the six months ended June 30, 2016, there were no transfers between Level 1 and 2. CenterPoint Energy also recognizes 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 CenterPoint Energy’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015, and indicate the fair value hierarchy of the valuation techniques utilized by CenterPoint Energy to determine such fair value.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of June 30, 2016
	(in millions)
Assets
Corporate equities	$	739	$	—	$	—	$	—		$	739
Investments, including money market funds (2)	55		—		—		—			55
Natural gas derivatives (3)	7		77		21		(36		)	69
Total assets	$	801	$	77	$	21	$	(36	)	$	863
Liabilities
Indexed debt securities derivative	$	—	$	490	$	—	$	—		$	490
Interest rate derivatives	—		2		—		—			2
Natural gas derivatives (3)	5		49		5		(36		)	23
Total liabilities	$	5	$	541	$	5	$	(36	)	$	515

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of less than $1 million 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.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of December 31, 2015
	(in millions)
Assets
Corporate equities	$	807	$	—	$	—	$	—		$	807
Investments, including money market funds (2)	53		—		—		—			53
Natural gas derivatives (3)	4		115		21		(15		)	125
Total assets	$	864	$	115	$	21	$	(15	)	$	985
Liabilities
Indexed debt securities derivative	$	—	$	442	$	—	$	—		$	442
Natural gas derivatives (3)	13		65		9		(71		)	16
Total liabilities	$	13	$	507	$	9	$	(71	)	$	458

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $56 million posted with the same counterparties.

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(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 has utilized Level 3 inputs to determine fair value:

	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative assets and liabilities, net
	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(in millions)
Beginning balance	$	15		$	13		$	12		$	17
Purchases	12			—			12			—
Total gains	—			—			4			—
Total settlements	(11		)	(3		)	(16		)	(6		)
Transfers into Level 3	—			—			5			—
Transfers out of Level 3	—			—			(1		)	(1		)
Ending balance (1)	$	16		$	10		$	16		$	10
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	3		$	—		$	11		$	2

(1) CenterPoint Energy did not have significant Level 3 sales during either of the three or six months ended June 30, 2016 or 2015.

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 the market price. These assets and liabilities, which are not measured at fair value in the Condensed Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 or Level 2 in the fair value hierarchy.

	June 30, 2016				December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial assets:
Notes receivable – unconsolidated affiliate	$	—	$	—	$	363	$	356
Financial liabilities:
Long-term debt	$	8,432	$	9,207	$	8,585	$	9,067

(8) Unconsolidated Affiliate

On May 1, 2013 (the Formation Date) CERC Corp., OGE and ArcLight closed on the formation of Enable. CenterPoint Energy has the ability to significantly influence the operating and financial policies of Enable and, accordingly, accounts for its investment in Enable’s common and subordinated units using the equity method of accounting.

CenterPoint Energy’s maximum exposure to loss related to Enable, a VIE in which CenterPoint Energy is not the primary beneficiary, is limited to its equity investment and preferred unit investment as presented in the Condensed Consolidated Balance Sheets as of June 30, 2016, the guarantees discussed in Note 14, and outstanding current accounts receivable from Enable. On February 18, 2016, CenterPoint Energy purchased in a Private Placement an aggregate of 14,520,000 Series A Preferred Units

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from Enable for a total purchase price of $363 million, which is accounted for as a cost method investment. During the three months ended June 30, 2016, CenterPoint Energy received a cash distribution of approximately $4 million for the partial period from February 18, 2016 through March 31, 2016 with respect to its investment in Series A Preferred Units. In connection with the Private Placement, Enable redeemed $363 million of notes owed to a wholly-owned subsidiary of CERC Corp., which bore interest at an annual rate of 2.10% to 2.45%. CenterPoint Energy recorded interest income of $-0- and $2 million during the three months ended June 30, 2016 and 2015, respectively, and $1 million and $4 million during the six months ended June 30, 2016 and 2015, respectively, and had interest receivable from Enable of $-0- and $4 million as of June 30, 2016 and December 31, 2015, respectively, on its notes receivable.

Effective on the Formation Date, CenterPoint Energy and Enable entered into the Transition Agreements. Under the Services Agreement, CenterPoint Energy agreed to provide certain support services to Enable such as accounting, legal, risk management and treasury functions for an initial term, which ended on April 30, 2016.  CenterPoint Energy is providing certain services to Enable on a year-to-year basis. Enable may terminate (i) the entire Services Agreement with at least 90 days’ notice prior to the end of any extension term, or (ii) either any service provided under the Services Agreement, or the entire Services Agreement, at any time upon approval by its board of directors and with at least 180 days’ notice.

CenterPoint Energy billed Enable for reimbursement of transition services of $2 million during both the three months ended June 30, 2016 and 2015, and $5 million and $7 million during the six months ended June 30, 2016 and 2015, respectively, under the Transition Agreements. Actual transition services costs are recorded net of reimbursements received from Enable. CenterPoint Energy had accounts receivable from Enable of $1 million and $3 million as of June 30, 2016 and December 31, 2015, respectively, for amounts billed for transition services.

CenterPoint Energy incurred natural gas expenses, including transportation and storage costs, of $24 million and $26 million during the three months ended June 30, 2016 and 2015, respectively, and $57 million and $65 million during the six months ended June 30, 2016 and 2015, respectively, for transactions with Enable. CenterPoint Energy had accounts payable to Enable of $8 million and $11 million as of June 30, 2016 and December 31, 2015, respectively, from such transactions.

As of June 30, 2016, CenterPoint Energy held an approximate 55.4% limited partner interest in Enable, consisting of 94,151,707 common units and 139,704,916 subordinated units. As of June 30, 2016, CenterPoint Energy and OGE each own a 50% management interest in the general partner of Enable and a 40% and 60% interest, respectively, in the incentive distribution rights held by the general partner. Additionally, as of June 30, 2016, CenterPoint Energy held 14,520,000 Series A Preferred Units in Enable.

CenterPoint Energy evaluates its equity method investments and cost method investments for impairment when factors indicate that a decrease in value of its investment has occurred and the carrying amount of its investment may not be recoverable. An impairment loss, based on the excess of the carrying value over the best estimate of fair value of the investment, is recognized in earnings when an impairment is deemed to be other than temporary. Considerable judgment is used in determining if an impairment loss is other than temporary and the amount of any impairment. As of June 30, 2016, the carrying value of CenterPoint Energy’s equity method investment in Enable was $10.85 per unit, which includes limited partner common and subordinated units, a general partner interest and incentive distribution rights. On June 30, 2016, Enable’s common unit price closed at $13.51.

As there were no identified events or changes in circumstances that may have a significant adverse effect on the fair value of CenterPoint Energy’s cost method investment in Enable’s Series A Preferred Units as of June 30, 2016, and the investment’s fair value is not readily determinable, an estimate of the fair value of the cost method investment was not performed.

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Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Operating revenues	$	529	$	590	$	1,038	$	1,206
Cost of sales, excluding depreciation and amortization	254		277		449		569
Operating income	57		93		160		197
Net income attributable to Enable	35		77		121		168
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	19	$	42	$	67	$	93
Basis difference amortization	12		1		24		2
CenterPoint Energy’s equity in earnings, net	$	31	$	43	$	91	$	95

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

	June 30, 2016			December 31, 2015
	(in millions)
Current assets	$	349		$	381
Non-current assets	10,851			10,857
Current liabilities	301			615
Non-current liabilities	3,150			3,092
Non-controlling interest	11			12
Preferred equity	362			—
Enable partners’ equity	7,376			7,519
Reconciliation of Equity Method Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ capital	$	4,084		$	4,163
CenterPoint Energy’s basis difference	(1,548		)	(1,569		)
CenterPoint Energy’s equity method investment in Enable	$	2,536		$	2,594

Distributions Received from Unconsolidated Affiliate:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	75	$	73	$	149	$	145

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(9) Goodwill

Goodwill by reportable business segment as of December 31, 2015 and changes in the carrying amount of goodwill as of June 30, 2016 are as follows:

	December 31, 2015			Continuum Acquisition (1)		June 30, 2016
	(in millions)
Natural Gas Distribution	$	746		$	—	$	746
Energy Services	83		(2)	21		104
Other Operations	11			—		11
Total	$	840		$	21	$	861

(1) See Note 3.

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

(10) Capital Stock

CenterPoint Energy, Inc. has 1,020,000,000 authorized shares of capital stock, comprised of 1,000,000,000 shares of $0.01 par value common stock and 20,000,000 shares of $0.01 par value cumulative preferred stock. As of June 30, 2016, 430,681,657 shares of CenterPoint Energy, Inc. common stock were issued and 430,681,491 shares were outstanding. As of December 31, 2015, 430,262,869 shares of CenterPoint Energy, Inc. common stock were issued and 430,262,703 shares were outstanding. Outstanding common shares exclude 166 treasury shares as of both June 30, 2016 and December 31, 2015.

(11) Indexed Debt Securities (ZENS) and Securities Related to ZENS

(a) Investment in Securities Related to ZENS

In 1995, CenterPoint Energy sold a cable television subsidiary to TW and received TW securities as partial consideration. A subsidiary of CenterPoint Energy now holds 7.1 million shares of TW Common, 0.9 million shares of Time Common and 0.9 million shares of Charter Common, 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 TW Securities are recorded in CenterPoint Energy’s Statements of Consolidated Income.

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1 billion of which $828 million remain outstanding at June 30, 2016. Each ZENS note 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 note are adjusted for certain corporate events. Prior to the merger described below, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.125505 share of TWC Common and 0.0625 share of Time Common.

On May 26, 2015, Charter announced that it had entered into a definitive merger agreement with TWC. On September 21, 2015, Charter shareholders approved the announced transaction with TWC. Pursuant to the merger agreement, upon closing of the merger, TWC Common would be exchanged for cash and Charter Common and as a result, reference shares for the ZENS would consist of Charter Common, TW Common and Time Common. The merger closed on May 18, 2016. CenterPoint Energy received $100 and 0.4891 shares of Charter Common for each share of TWC Common held, resulting in cash proceeds of $178 million and 872,531 shares of Charter Common. In accordance with the terms of the ZENS, CenterPoint Energy remitted $178 million to ZENS note holders in June 2016, which reduced contingent principal.  As a result, CenterPoint Energy recorded the following:

	(in millions)
Cash payment to ZENS note holders	$	178
Indexed debt – reduction	(40		)
Indexed debt securities derivative – reduction	(21		)
Loss on indexed debt securities	$	117

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As of June 30, 2016, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.0625 share of Time Common and 0.061382 share of Charter Common, and the contingent principal balance was $519 million.

(12) Short-term Borrowings and Long-term Debt

(a) Short-term Borrowings

Inventory Financing. NGD has asset management agreements associated with its utility distribution service in Arkansas, north Louisiana and Oklahoma that extend through 2019. 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 a financing and had an associated principal obligation of $17 million and $40 million as of June 30, 2016 and December 31, 2015, respectively.

(b) Long-term Debt

Debt Repayments. In May 2016, CERC retired approximately $325 million aggregate principal amount of its 6.15% senior notes at their maturity. The retirement of senior notes was financed by the issuance of commercial paper.

Houston Electric General Mortgage Bonds. In May 2016, Houston Electric issued $300 million aggregate principal amount of 1.85% general mortgage bonds due 2021. The proceeds from the issuance of the bonds were used to repay short-term debt and for general corporate purposes.

Credit Facilities. On March 4, 2016, CenterPoint Energy announced that it had refinanced its existing $2.1 billion revolving credit facilities, which would have expired in 2019, with new revolving credit facilities totaling an aggregate $2.5 billion. The credit agreements evidencing the new revolving credit facilities provide for five-year senior unsecured revolving credit facilities in amounts of $1.6 billion for CenterPoint Energy, $300 million for Houston Electric and $600 million for CERC Corp.

As of June 30, 2016 and December 31, 2015, CenterPoint Energy, Houston Electric and CERC Corp. had the following revolving credit facilities and utilization of such facilities:

	June 30, 2016									December 31, 2015
	Size of Facility		Loans		Letters of Credit		Commercial Paper			Size of Facility		Loans			Letters of Credit		Commercial Paper
	(in millions)
CenterPoint Energy	$	1,600	$	—	$	6	$	1,037	(1)	$	1,200	$	—		$	6	$	716	(1)
Houston Electric	300		—		4		—			300		200		(2)	4		—
CERC Corp.	600		—		3		176		(3)	600		—			2		219		(3)
Total	$	2,500	$	—	$	13	$	1,213		$	2,100	$	200		$	12	$	935

(1) Weighted average interest rate was 0.82% and 0.79% as of June 30, 2016 and December 31, 2015, respectively.

(2) Weighted average interest rate was 1.637% as of December 31, 2015.

(3) Weighted average interest rate was 0.68% and 0.81% as of June 30, 2016 and December 31, 2015, respectively.

CenterPoint Energy’s $1.6 billion revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CenterPoint Energy’s current credit ratings. The revolving credit facility contains a financial covenant which limits CenterPoint Energy’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of CenterPoint Energy’s consolidated capitalization. As of June 30, 2016, CenterPoint Energy’s debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 55.5%. 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 twelve-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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Houston Electric’s $300 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.125% based on Houston Electric’s current credit ratings. The revolving credit facility contains a financial covenant which limits Houston Electric’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of Houston Electric’s consolidated capitalization. As of June 30, 2016, Houston Electric’s debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 52.7%. 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 Houston Electric certifies to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-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 Houston Electric delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of Houston Electric’s certification or (iii) the revocation of such certification.

CERC Corp.’s $600 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CERC Corp.’s current credit ratings. The revolving credit facility contains a financial covenant which limits CERC’s consolidated debt to an amount not to exceed 65% of CERC’s consolidated capitalization. As of June 30, 2016, CERC’s debt to capital ratio, as defined in its credit facility agreement, was 30.7%.

CenterPoint Energy, Houston Electric and CERC Corp. were in compliance with all financial covenants as of June 30, 2016.

(13) Income Taxes

The effective tax rate reported for the three months ended June 30, 2016 was 125% compared to 32% for the same period in 2015. The higher effective tax rate for the three months ended June 30, 2016 is due to a Louisiana state tax law change resulting in an increase to CenterPoint Energy’s deferred tax liability, the effect of which was compounded by lower earnings.

The effective tax rate reported for the six months ended June 30, 2016 was 39% compared to 36% for the same period in 2015. The higher effective tax rate for the six months ended June 30, 2016 is due to a Louisiana state tax law change discussed above.

CenterPoint Energy reported no uncertain tax liability as of June 30, 2016 and expects no significant change to the uncertain tax liability over the next twelve months. CenterPoint Energy’s consolidated federal income tax returns have been audited and settled through 2014. CenterPoint Energy is under examination by the IRS for 2015 and 2016.

(14) Commitments and Contingencies

(a) Natural Gas Supply Commitments

Natural gas supply commitments include natural gas contracts related to CenterPoint Energy’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 Condensed Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015 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, 2016, minimum payment obligations for natural gas supply commitments are approximately $190 million for the remaining six months in 2016, $473 million in 2017, $456 million in 2018, $270 million in 2019, $132 million in 2020 and $127 million after 2020.

(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, nor does it affect the terms of existing guarantee arrangements for certain GenOn gas transportation contracts discussed below.

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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. That ruling is subject to appeal. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims.  CenterPoint Energy does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows.

Environmental Matters

Manufactured Gas Plant Sites. 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, 2016, 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 Environmental Protection Agency 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 does 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 CenterPoint Energy or its predecessors contain or have contained asbestos insulation and other asbestos-containing materials. CenterPoint Energy and its subsidiaries 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 CenterPoint Energy anticipates that additional claims may be asserted in the future.  Although their ultimate outcome cannot be predicted at this time, CenterPoint Energy does not expect these matters, either individually or in the aggregate, to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

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

Other Proceedings

CenterPoint Energy is 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, CenterPoint Energy is also a defendant 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. CenterPoint Energy regularly analyzes current information and, as necessary, provides accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. CenterPoint Energy does not expect the disposition of these matters to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

(c) Guarantees

Prior to the distribution of CenterPoint Energy’s ownership in RRI to its shareholders, CERC had guaranteed certain contractual obligations of what became RRI’s trading subsidiary.  When the companies separated, RRI agreed to secure CERC against obligations under the guarantees RRI had been unable to extinguish by the time of separation.  Pursuant to such agreement, as amended in December 2007, RRI (now GenOn) agreed to provide to CERC cash or letters of credit as security against CERC’s obligations under its remaining guarantees for demand charges under certain gas transportation agreements if and to the extent changes in market conditions expose CERC to a risk of loss on those guarantees based on an annual calculation, with any required collateral to be posted each December.  The undiscounted maximum potential payout of the demand charges under these

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transportation contracts, which will be in effect until 2018, was approximately $20 million as of June 30, 2016.  Based on market conditions in the fourth quarter of 2015 at the time the most recent annual calculation was made under the agreement, GenOn was not obligated to post any security. If GenOn should fail to perform the contractual obligations, CERC could have to honor its guarantee and, in such event, any collateral then provided as security may be insufficient to satisfy CERC’s obligations.

In 2010, CenterPoint Energy provided a guarantee (the CenterPoint Midstream Guarantee) with respect to the performance of certain obligations of Enable under a long-term gas gathering and treating agreement with an indirect, wholly-owned subsidiary of Royal Dutch Shell plc. Under the terms of the omnibus agreement entered into in connection with the closing of the formation of Enable, Enable and CenterPoint Energy have agreed to use commercially reasonable efforts and cooperate with each other to terminate the CenterPoint Midstream Guarantee and to release CenterPoint Energy from such guarantee. As of June 30, 2016, CenterPoint Energy had guaranteed Enable’s obligations up to an aggregate amount of $50 million under the CenterPoint Midstream Guarantee.

CERC Corp. had also provided a guarantee of collection of $1.1 billion of Enable’s senior notes due 2019 and 2024. This guarantee was subordinated to all senior debt of CERC Corp. and was automatically released on May 1, 2016.

The fair value of these guarantees is not material.

(15) Earnings Per Share

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016				2015		2016		2015
	(in millions, except share and per share amounts)
Net income (loss)	$	(2	)		$	77	$	152	$	208
Basic weighted average shares outstanding	430,653,000				430,235,000		430,530,000		430,096,000
Plus: Incremental shares from assumed conversions:
Restricted stock	—			(1)	1,498,000		2,443,000		1,498,000
Diluted weighted average shares	430,653,000				431,733,000		432,973,000		431,594,000
Basic earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48
Diluted earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48

(1) 2,443,000 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 months ended June 30, 2016, as their inclusion would be anti-dilutive.

(16) Reportable Business Segments

CenterPoint Energy’s determination of reportable business segments considers the strategic operating units under which CenterPoint Energy manages sales, allocates resources and assesses performance of various products and services to wholesale or retail customers in differing regulatory environments. CenterPoint Energy uses operating income as the measure of profit or loss for its business segments.

CenterPoint Energy’s reportable business segments include the following: Electric Transmission & Distribution, Natural Gas Distribution, Energy Services, Midstream Investments and Other Operations. The electric transmission and distribution function is reported in the Electric Transmission & Distribution business segment. 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 represents CenterPoint Energy’s non-rate regulated gas sales and services operations. Midstream Investments consists of CenterPoint Energy’s investment in Enable. Other Operations consists primarily of other corporate operations which support all of CenterPoint Energy’s business operations.

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Financial data for business segments is as follows:

	For the Three Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	763	(1)	$	—		$	158
Natural Gas Distribution	414			7			20
Energy Services	393			4			—
Midstream Investments (2)	—			—			—
Other Operations	4			—			4
Eliminations	—			(11		)	—
Consolidated	$	1,574		$	—		$	182

	For the Three Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	705	(1)	$	—		$	158
Natural Gas Distribution	420			7			19
Energy Services	404			4			9
Midstream Investments (2)	—			—			—
Other Operations	3			—			—
Eliminations	—			(11		)	—
Consolidated	$	1,532		$	—		$	186

	For the Six Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of June 30, 2016
	(in millions)
Electric Transmission & Distribution	$	1,423	(1)	$	—		$	241	$	10,065
Natural Gas Distribution	1,302			14			180		5,585
Energy Services	825			11			6		973
Midstream Investments (2)	—			—			—		2,536
Other Operations	8			—			5		2,771			(3)
Eliminations	—			(25		)	—		(918		)
Consolidated	$	3,558		$	—		$	432	$	21,012

	For the Six Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of December 31, 2015
	(in millions)
Electric Transmission & Distribution	$	1,317	(1)	$	—		$	254	$	10,028
Natural Gas Distribution	1,605			15			165		5,657
Energy Services	1,036			22			22		857
Midstream Investments (2)	—			—			—		2,594
Other Operations	7			—			1		2,879			(3)
Eliminations	—			(37		)	—		(725		)
Consolidated	$	3,965		$	—		$	442	$	21,290

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(1) Electric Transmission & Distribution revenues from major customers are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Affiliates of NRG	$	159	$	172	$	304	$	356
Affiliates of Energy Future Holdings Corp.	$	50	$	51	$	95	$	103

(2) Midstream Investments’ equity earnings are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	31	$	43	$	91	$	95

Midstream Investments’ total assets are as follows:

	June 30, 2016		December 31, 2015
	(in millions)
Enable	$	2,536	$	2,594

(3) Included in total assets of Other Operations as of June 30, 2016 and December 31, 2015 are pension and other postemployment-related regulatory assets of $791 million and $814 million, respectively.

(17) Subsequent Events

On July 28, 2016, CenterPoint Energy’s board of directors declared a regular quarterly cash dividend of $0.2575 per share of common stock payable on September 9, 2016, to shareholders of record as of the close of business on August 16, 2016.

On August 2, 2016, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common and subordinated units for the quarter ended June 30, 2016. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million from Enable in the third quarter of 2016 to be made with respect to CERC Corp.’s investment in common and subordinated units in Enable for the second quarter of 2016.

On August 2, 2016, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended June 30, 2016. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the third quarter of 2016 to be made with respect to CenterPoint Energy’s investment in Series A Preferred Units of Enable for the second quarter of 2016.

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

The following discussion and analysis should be read in combination with our Interim Condensed Financial Statements contained in this Form 10-Q and our 2015 Form 10-K.

RECENT EVENTS

Continuum Acquisition. On April 1, 2016,CES, our indirect, wholly-owned subsidiary, closed the previously announced agreement to acquire the retail energy services business and natural gas wholesale assets of Continuum for $98 million. For more information regarding the acquisition, see Note 3 of our Interim Condensed Financial Statements.

Charter Merger. On May 26, 2015, Charter announced that it had entered into a definitive merger agreement with TWC. On September 21, 2015, Charter shareholders approved the announced transaction with TWC. Pursuant to the merger agreement, upon closing of the merger, TWC Common would be exchanged for cash and Charter Common. The merger closed on May 18, 2016. For further information regarding the Charter merger, see Note 11 to our Interim Condensed Financial Statements.

Houston Electric General Mortgage Bonds.In May 2016, Houston Electric issued $300 million aggregate principal amount of 1.85% general mortgage bonds due 2021. The proceeds from the issuance of the bonds were used to repay short-term debt and for general corporate purposes.

DCRF. In April 2016, Houston Electric filed an application with the Texas Utility Commission for a DCRF interim rate adjustment to account for changes in certain distribution-invested capital since its 2010 rate case.  The application requested the annualized DCRF charge to be set at $49.4 million.  This charge, effective September 1, 2016 through August 31, 2017, is based on an increase in eligible distribution-invested capital from January 1, 2010 through December 31, 2015 of $689 million.  In June 2016, the parties reached a settlement providing for an annualized DCRF charge of $45 million effective September 2016 and, unless otherwise changed in a subsequent DCRF filing, an annualized DCRF charge of $49 million effective September 2017. In July 2016, the Texas Utility Commission approved the settlement.

Houston, South Texas, Beaumont/East Texas and Texas Coast GRIP. NGD’s Houston, South Texas, Beaumont/East Texas and Texas Coast divisions each submitted annual GRIP filings in March 2016 representing an aggregate increase in revenue of $18.2 million based on incremental capital expenditures of $115.5 million. For each division, rates were approved and implemented by July 2016.

Minnesota Rate Case. In August 2015, NGD filed a general rate case with the MPUC requesting an annual increase of $54.1 million.  In September 2015, the MPUC approved an interim increase of $47.8 million in revenues effective October 2, 2015, subject to a refund. The MPUC order was issued in June 2016 authorizing a $27.5 million rate adjustment based on an ROE of 9.49% and an ROR of 7.07%. On June 23, 2016, NGD filed a request for reconsideration. The MPUC has 60 days to take action or the reconsideration request is deemed denied by operation of law. The interim rate refund and final rates can only be implemented after the required compliance filing is accepted by the MPUC.

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CONSOLIDATED RESULTS OF OPERATIONS

All dollar amounts in the tables that follow are in millions, except for per share amounts.

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Revenues	$	1,574		$	1,532		$	3,558		$	3,965
Expenses	1,392			1,346			3,126			3,523
Operating Income	182			186			432			442
Interest and Other Finance Charges	(86		)	(89		)	(173		)	(178		)
Interest on Securitization Bonds	(23		)	(27		)	(47		)	(55		)
Equity in Earnings of Unconsolidated Affiliate, net	31			43			91			95
Other Income, net	(96		)	1			(55		)	19
Income Before Income Taxes	8			114			248			323
Income Tax Expense	10			37			96			115
Net Income (Loss)	$	(2	)	$	77		$	152		$	208
Basic Earnings (Loss) Per Share	$	(0.01	)	$	0.18		$	0.35		$	0.48
Diluted Earnings (Loss) Per Share	$	(0.01	)	$	0.18		$	0.35		$	0.48

Three months ended June 30, 2016 compared to three months ended June 30, 2015

We reported a net loss of $2 million ($(0.01) per diluted share) for the three months ended June 30, 2016 compared to net income of $77 million ($0.18 per diluted share) for the same period in 2015.

The decrease in net income of $79 million was due to the following key factors:

• a $59 million decrease in the gain on marketable securities included in Other Income, net shown above;

• a $39 million increase in the loss on indexed debt securities related to the ZENS included in Other Income, net shown above, resulting from a loss of $117 million from the Charter merger in 2016 compared to a loss of $7 million from Verizon’s acquisition of AOL in 2015, partially offset by decreased losses of $71 million in the underlying value of the indexed debt securities;

• a $12 million decrease in equity earnings from our investment in Enable; and

• a $4 million decrease in operating income (discussed by segment below).

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

•a $27 million decrease in income tax expense;

•a $4 million decrease in interest expense related to lower outstanding balances of our Securitization Bonds;

•a $3 million decrease in interest expense due to lower weighted average interest rates on outstanding debt; and

•a $1 million increase in other income included in Other Income, net shown above.

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Six months ended June 30, 2016 compared to six months ended June 30, 2015

We reported net income of $152 million ($0.35 per diluted share) for the six months ended June 30, 2016 compared to net income of $208 million ($0.48 per diluted share) for the same period in 2015.

The decrease in net income of $56 million was due to the following key factors:

• a $119 million increase in the loss on indexed debt securities related to the ZENS included in Other Income, net shown above, resulting from a loss of $117 million from the Charter merger in 2016 compared to a loss of $7 million from Verizon’s acquisition of AOL in 2015, partially offset by increased losses of $9 million in the underlying value of the indexed debt securities;

• a $10 million decrease in operating income (discussed by segment below);

• a $4 million decrease in equity earnings from our investment in Enable; and

• a $3 million decrease in other income included in Other Income, net shown above.

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

• a $48 million increase in the gain on marketable securities included in Other Income, net shown above;

•a $19 million decrease in income tax expense;

•an $8 million decrease in interest expense related to lower outstanding balances of our Securitization Bonds; and

•a $5 million decrease in interest expense due to lower weighted average interest rates on outstanding debt.

Income Tax Expense

Our effective tax rate reported for the three months ended June 30, 2016 was 125% compared to 32% for the same period in 2015. The higher effective tax rate for the three months ended June 30, 2016 is due to a Louisiana state tax law change resulting in an increase to our deferred tax liability, the effect of which was compounded by lower earnings. The effective tax rate reported for the six months ended June 30, 2016 was 39% compared to 36% for the same period in 2015. The higher effective tax rate for the six months ended June 30, 2016 is due to a Louisiana state tax law change discussed above. We expect our annual effective tax rate for the period ended December 31, 2016 to be approximately 37%.

RESULTS OF OPERATIONS BY BUSINESS SEGMENT

The following table presents operating income for each of our business segments for the three and six months ended June 30, 2016 and 2015.  Included in revenues are intersegment sales. We account for intersegment sales as if the sales were to third parties at current market prices.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Electric Transmission & Distribution	$	158	$	158	$	241	$	254
Natural Gas Distribution	20		19		180		165
Energy Services	—		9		6		22
Other Operations	4		—		5		1
Total Consolidated Operating Income	$	182	$	186	$	432	$	442

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Electric Transmission & Distribution

For information regarding factors that may affect the future results of operations of our 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 our 2015 Form 10-K.

The following table provides summary data of our Electric Transmission & Distribution business segment for the three and six months ended June 30, 2016 and 2015:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions, except throughput and customer data)
Revenues:
TDU	$	616	$	585	$	1,156	$	1,099
Bond Companies	147		120		267		218
Total revenues	763		705		1,423		1,317
Expenses:
Operation and maintenance, excluding Bond Companies	330		315		659		622
Depreciation and amortization, excluding Bond Companies	94		84		189		167
Taxes other than income taxes	57		55		114		111
Bond Companies	124		93		220		163
Total expenses	605		547		1,182		1,063
Operating Income	$	158	$	158	$	241	$	254
Operating Income:
TDU	$	135	$	131	$	194	$	199
Bond Companies (1)	23		27		47		55
Total segment operating income	$	158	$	158	$	241	$	254
Throughput (in GWh):
Residential	7,632		7,483		12,651		12,896
Total	22,190		21,751		40,321		39,766
Number of metered customers at end of period:
Residential	2,106,396		2,054,777		2,106,396		2,054,777
Total	2,377,352		2,322,164		2,377,352		2,322,164

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

Three months ended June 30, 2016 compared to three months ended June 30, 2015

Our Electric Transmission & Distribution business segment reported operating income of $158 million for the three months ended June 30, 2016, consisting of $135 million from the TDU and $23 million related to Bond Companies. For the three months ended June 30, 2015, operating income totaled $158 million, consisting of $131 million from the TDU and $27 million related to Bond Companies.

TDU operating income increased $4 million due to the following key factors:

• higher transmission-related revenues of $20 million, which were partially offset by increased transmission costs billed by transmission providers of $12 million;

• customer growth of $8 million from the addition of over 55,000 new customers;

• higher equity return of $5 million, primarily related to true-up proceeds; and

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• higher right-of-way revenues of $1 million.

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

• higher depreciation, primarily due to ongoing additions to plant in service, and other taxes of $12 million;

• lower usage of $4 million, primarily due to milder weather; and

• higher operation and maintenance expenses of $3 million.

Six months ended June 30, 2016 compared to six months ended June 30, 2015

Our Electric Transmission & Distribution business segment reported operating income of $241 million for the six months ended June 30, 2016, consisting of $194 million from the TDU and $47 million related to Bond Companies. For the six months ended June 30, 2015, operating income totaled $254 million, consisting of $199 million from the TDU and $55 million related to Bond Companies.

TDU operating income decreased $5 million due to the following key factors:

• higher depreciation, primarily due to ongoing additions to plant in service, and other taxes of $25 million;

• higher operation and maintenance expenses of $9 million;

• lower usage of $7 million, primarily due to milder weather;

• lower right-of-way revenue of $5 million; and

• energy efficiency of $1 million due to amortization of the remand bonus recognized in 2015.

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

• higher transmission-related revenues of $47 million, which were partially offset by increased transmission costs billed by transmission providers of $28 million;

• customer growth of $14 million from the addition of over 55,000 new customers; and

• higher equity return of $10 million, primarily related to true-up proceeds.

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Natural Gas Distribution

For information regarding factors that may affect the future results of operations of our 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 our 2015 Form 10-K.

The following table provides summary data of our Natural Gas Distribution business segment for the three and six months ended June 30, 2016 and 2015:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions, except throughput and customer data)
Revenues	$	421	$	427	$	1,316	$	1,620
Expenses:
Natural gas	130		152		575		908
Operation and maintenance	178		169		367		355
Depreciation and amortization	60		55		119		110
Taxes other than income taxes	33		32		75		82
Total expenses	401		408		1,136		1,455
Operating Income	$	20	$	19	$	180	$	165
Throughput (in Bcf):
Residential	20		19		93		116
Commercial and industrial	56		56		142		144
Total Throughput	76		75		235		260
Number of customers at end of period:
Residential	3,145,655		3,112,902		3,145,655		3,112,902
Commercial and industrial	252,172		249,142		252,172		249,142
Total	3,397,827		3,362,044		3,397,827		3,362,044

Three months ended June 30, 2016 compared to three months ended June 30, 2015

Our Natural Gas Distribution business segment reported operating income of $20 million for the three months ended June 30, 2016, compared to $19 million for the three months ended June 30, 2015.

Operating income increased $1 million as a result of the following key factors:

• rate increases of $9 million;

• increased miscellaneous revenues of $4 million, primarily due to weather-related decoupling and increased usage due to improved economic activity in Minnesota; and

• customer growth of $2 million from the addition of approximately 36,000 new customers.

These increases were partially offset by the following:

• higher depreciation, primarily due to ongoing additions to plant in service, and other taxes of $7 million;

• increased contractor services expense of $5 million, primarily due to pipeline integrity work and higher disconnect activities that are recovered when service is reconnected; and

• increased labor and benefits expense of $2 million.

Increased expense related to energy efficiency programs of $1 million and decreased expense related to gross receipt taxes of $1 million were offset by corresponding offsets in the related revenues.

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Six months ended June 30, 2016 compared to six months ended June 30, 2015

Our Natural Gas Distribution business segment reported operating income of $180 million for the six months ended June 30, 2016, compared to $165 million for the six months ended June 30, 2015.

Operating income increased $15 million as a result of the following key factors:

• rate increases of $31 million; and

• customer growth of $3 million from the addition of approximately 36,000 new customers.

These increases were partially offset by the following:

• higher depreciation, primarily due to ongoing additions to plant in service, and other taxes of $10 million;

• increased contractor services expense of $6 million, primarily due to pipeline integrity work and higher disconnect activities that are recovered when service is reconnected; and

• increased labor and benefits expense of $4 million.

Decreased expense related to gross receipt taxes of $8 million were offset by a corresponding decrease in the related revenues.

Energy Services

For information regarding factors that may affect the future results of operations of our 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 our 2015 Form 10-K.

The following table provides summary data of our Energy Services business segment for the three and six months ended June 30, 2016 and 2015:

	Three Months Ended June 30,					Six Months Ended June 30,
	2016			2015		2016			2015
	(in millions, except throughput and customer data)
Revenues	$	397		$	408	$	836		$	1,058
Expenses:
Natural gas	377			388		798			1,012
Operation and maintenance	17			9		27			21
Depreciation and amortization	3			1		4			2
Taxes other than income taxes	—			1		1			1
Total expenses	397			399		830			1,036
Operating Income	$	—		$	9	$	6		$	22
Mark-to-market gain (loss)	$	(7	)	$	2	$	(16	)	$	(2	)
Throughput (in Bcf)	199			136		370			321
Number of customers at end of period	30,675			18,073		30,675			18,073

Three months ended June 30, 2016 compared to three months ended June 30, 2015

Our Energy Services business segment reported operating income of $-0- for the three months ended June 30, 2016 compared to $9 million for the three months ended June 30, 2015.  The decrease in operating income of $9 million was primarily due to a

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$9 million decrease from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins.  The second quarter of 2016 included a $7 million mark-to-market charge compared to a $2 million mark-to-market benefit for the same period of 2015. The second quarter of 2016 also included $2 million of operation and maintenance expenses and $1 million of amortization expenses related to the acquisition and integration of Continuum.

Six months ended June 30, 2016 compared to six months ended June 30, 2015

Our Energy Services business segment reported operating income of $6 million for the six months ended June 30, 2016 compared to $22 million for the six months ended June 30, 2015.  The decrease in operating income of $16 million was primarily due to a $14 million decrease from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins. The first half of 2016 included a $16 million mark-to-market charge compared to a $2 million mark-to-market charge for the same period of 2015. The six months ended June 30, 2016 also included $2 million of operation and maintenance expenses and $1 million of amortization expenses related to the acquisition and integration of Continuum. The remaining decrease in operating income was margin related, resulting primarily from reduced weather-related optimization opportunities of existing gas transportation assets.

Midstream Investments

For information regarding factors that may affect the future results of operations of our 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 our 2015 Form 10-K.

The following table provides pre-tax equity income of our Midstream Investments business segment for the three and six months ended June 30, 2016 and 2015:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	31	$	43	$	91	$	95

Other Operations

The following table shows the operating income of our Other Operations business segment for the three and six months ended June 30, 2016 and 2015:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Revenues	$	4	$	3	$	8	$	7
Expenses	—		3		3		6
Operating Income	$	4	$	—	$	5	$	1

CERTAIN FACTORS AFFECTING FUTURE EARNINGS

For information on other developments, factors and trends that may have an impact on our 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 our 2015 Form 10-K, “Risk Factors” in Item 1A of Part I of our 2015 Form 10-K and “Cautionary Statement Regarding Forward-Looking Information” in this Form 10-Q.

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LIQUIDITY AND CAPITAL RESOURCES

Historical Cash Flows

The following table summarizes the net cash provided by (used in) operating, investing and financing activities for the six months ended June 30, 2016 and 2015:

	Six Months Ended June 30,
	2016			2015
	(in millions)
Cash provided by (used in):
Operating activities	$	1,058		$	1,122
Investing activities	(467		)	(671		)
Financing activities	(584		)	(504		)

Cash Provided by Operating Activities

Net cash provided by operating activities in the first six months of 2016 decreased $64 million compared to the same period in 2015 due tochanges inworking capital ($138 million), partially offset by higher net income after adjusting for non-cash and non-operating items ($50 million) (primarily depreciation and amortization and deferred income taxes) and increased cash from other non-current items ($24 million). The changes in working capital items in 2016 primarily related to decreased cash provided by fuel cost over recovery, natural gas storage inventory and net regulatory assets and liabilities, partially offset by increased cash provided by non-trading derivatives, net and margin deposits, net.

Cash Used in Investing Activities

Net cash used in investing activities in the first six months of 2016 decreased $204 million compared to the same period in 2015 due primarily to increased cash received for the repayment of notes receivable from Enable ($363 million), a return of capital from Enable ($149 million), increased proceeds from the sale of marketable securities associated with the Charter merger ($146 million) and decreased capital expenditures ($30 million), which were partially offset by increased cash used for the purchase of Series A Preferred Units ($363 million), increased cash used for the Continuum acquisition ($98 million) and increased restricted cash ($15 million).

Cash Used in Financing Activities

Net cash used by financing activities in the first six months of 2016 increased $80 million compared to the same period in 2015 due to increased payments of long-term debt ($335 million), increased distributions to ZENS note holders ($178 million), increased payment of common stock dividends ($8 million) and increased debt issuance costs ($7 million), which were partially offset by increased proceeds from the issuance of general mortgage bonds ($300 million), increased net proceeds from commercial paper ($141 million) and decreased short-term borrowings ($6 million).

Future Sources and Uses of Cash

Our liquidity and capital requirements are affected primarily by our results of operations, capital expenditures, debt service requirements, tax payments, working capital needs and various regulatory actions. Our capital expenditures are expected to be used for investment in infrastructure for our electric transmission and distribution operations and our natural gas distribution operations.  These capital expenditures are anticipated to maintain reliability and safety as well as expand our systems through value-added projects. Our principal anticipated cash requirements for the remaining six months of 2016 include the following:

• capital expenditures of approximately $695 million;

• scheduled principal payments on Securitization Bonds of $183 million;

• dividend payments on CenterPoint Energy, Inc. common stock; and

• interest payments on debt.

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We expect that borrowings under our credit facilities, proceeds from commercial paper, proceeds from the issuance of general mortgage bonds, anticipated cash flows from operations and distributions from Enable will be sufficient to meet our anticipated cash needs for the remaining six months of 2016. Discretionary financing or refinancing may result in the issuance of equity or debt securities in the capital markets or the arrangement of additional credit facilities. Issuances of equity or debt in the capital markets, funds raised in the commercial paper markets and additional credit facilities may not, however, be available to us on acceptable terms.

Off-Balance Sheet Arrangements

Prior to the distribution of our ownership in RRI to our shareholders, CERC had guaranteed certain contractual obligations of what became RRI’s trading subsidiary.  When the companies separated, RRI agreed to secure CERC against obligations under the guarantees RRI had been unable to extinguish by the time of separation.  Pursuant to such agreement, as amended in December 2007, RRI (now GenOn) agreed to provide to CERC cash or letters of credit as security against CERC’s obligations under its remaining guarantees for demand charges under certain gas transportation agreements if and to the extent changes in market conditions expose CERC to a risk of loss on those guarantees based on an annual calculation, with any required collateral to be posted each December.  The undiscounted maximum potential payout of the demand charges under these transportation contracts, which will be in effect until 2018, was approximately $20 million as of June 30, 2016.  Based on market conditions in the fourth quarter of 2015 at the time the most recent annual calculation was made under the agreement, GenOn was not obligated to post any security. If GenOn should fail to perform the contractual obligations, CERC could have to honor its guarantee and, in such event, any collateral provided as security may be insufficient to satisfy CERC’s obligations.

In 2010, CenterPoint Energy provided a guarantee (the CenterPoint Midstream Guarantee) with respect to the performance of certain obligations of Enable under a long-term gas gathering and treating agreement with an indirect, wholly-owned subsidiary of Royal Dutch Shell plc. Under the terms of the omnibus agreement entered into in connection with the closing of the formation of Enable, Enable and CenterPoint Energy have agreed to use commercially reasonable efforts and cooperate with each other to terminate the CenterPoint Midstream Guarantee and to release CenterPoint Energy from such guarantee. As of June 30, 2016, we have guaranteed Enable’s obligations up to an aggregate amount of $50 million under the CenterPoint Midstream Guarantee.

CERC Corp. had also provided a guarantee of collection of $1.1 billion of Enable’s senior notes due 2019 and 2024. This guarantee was subordinated to all senior debt of CERC Corp. and was automatically released on May 1, 2016.

The fair value of these guarantees is not material. Other than the guarantees described above and operating leases, we have no off-balance sheet arrangements.

Regulatory Matters

Significant regulatory developments that have occurred since our 2015 Form 10-K was filed with the SEC are discussed below.

Houston Electric

Brazos Valley Connection Project. In April 2016, the Texas Utility Commission issued an order on rehearing for the Brazos Valley Connection requiring Houston Electric to use steel monopoles in lieu of lattice towers for the construction to reduce the aesthetic impact of the project. The Texas Utility Commission’s original order provided an estimated range of approximately $270–$310 million for the capital costs for the Brazos Valley Connection. The actual cost will depend on factors including land acquisition costs, material and construction costs, and other factors.  Houston Electric expects to complete construction of the Brazos Valley Connection by mid-2018. 

DCRF. In April 2016, Houston Electric filed an application with the Texas Utility Commission for a DCRF interim rate adjustment to account for changes in certain distribution-invested capital since its 2010 rate case.  The application requested the annualized DCRF charge to be set at $49.4 million.  This charge, effective September 1, 2016 through August 31, 2017, is based on an increase in eligible distribution-invested capital from January 1, 2010 through December 31, 2015 of $689 million.  In June 2016, the parties reached a settlement providing for an annualized DCRF charge of $45 million effective September 2016 and, unless otherwise changed in a subsequent DCRF filing, an annualized DCRF charge of $49 million effective September 2017. In July 2016, the Texas Utility Commission approved the settlement.

EECRF.  In June 2016, Houston Electric filed an application with the Texas Utility Commission for an adjustment to its EECRF to recover $45.9 million in 2017, including an incentive of $10.6 million based on 2015 program performance.  Houston Electric requested approval effective by March 2017.

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TCOS. In July 2016, Houston Electric filed an application with the Texas Utility Commission for an interim update of its TCOS seeking an increase in annual revenues based on an incremental increase in total rate base of $95.6 million. Houston Electric expects to receive approval from the Texas Utility Commission during the third quarter of 2016. An increase of $3.5 million in annual revenues is expected based on this approval.

CERC

Houston, South Texas, Beaumont/East Texas and Texas Coast GRIP. NGD’s Houston, South Texas, Beaumont/East Texas and Texas Coast divisions each submitted annual GRIP filings on March 31, 2016 representing an aggregate increase in revenue of $18.2 million based on incremental capital expenditures of $115.5 million. For each division, rates were approved and implemented by July 2016.

Oklahoma PBRC. In March 2016, NGD made a PBRC filing for the 2015 calendar year proposing to increase revenues by $0.5 million. On July 19, 2016, the Oklahoma Corporation Commission approved a joint stipulation that provides for a 10% ROE, a capital structure of 45% debt and 55% equity and no change in rates.

Arkansas BDA.  In March 2016, NGD made its annual BDA filing with the APSC to request recovery of a calendar year 2015 shortfall of $5.5 million.  Rates were implemented in June 2016.

Arkansas Rate Case. In November 2015, NGD filed an Application for Approval of a General Change in Rates with the APSC seeking a $35.6 million increase in revenue requirement and a 10.3% ROE. A non-unanimous settlement agreement was reached with the APSC staff and certain other parties for an annual revenue increase of $14.2 million and a 9.5% ROE plus the adoption of an annual rate mechanism to recover future capital and expenses. A hearing was held in July 2016 for the APSC to consider the non-unanimous settlement. A final determination by the APSC is expected in the third quarter of 2016.

Louisiana RSP. NGD made its 2015 Louisiana RSP filings with the LPSC in October 2015. The North Louisiana Rider RSP filing shows a revenue deficiency of $1.0 million, and the South Louisiana Rider RSP filing shows a revenue deficiency of $1.5 million. Both 2015 Louisiana RSP filings utilized the capital structure and ROE factors approved by the LPSC in September 2015, which set an authorized ROE of 9.95% and a capital structure of 48% debt and 52% equity. NGD began billing in December 2015, subject to a refund. The 2015 Louisiana RSP filing is still subject to final approval from the LPSC. NGD made its 2014 Louisiana RSP filings with the LPSC in October 2014. The North Louisiana Rider RSP filing showed a revenue deficiency of $4.0 million, using the then-authorized ROE of 10.25% with a capital structure of 53% debt and 47% equity. The South Louisiana Rider RSP filing showed a revenue deficiency of $2.3 million, using the then-authorized ROE of 10.5% with a capital structure of 53% debt and 47% equity. NGD began billing the revised rates in December 2014, subject to refund or surcharge. After LPSC staff review and adjustments to conform to the RSP changes ordered by the LPSC in the 2013 RSP cases as approved in September 2015, NGD settled on an adjustment for the North Louisiana Rider RSP of $4.7 million, with an authorized ROE of 9.95% and a capital structure of 48% debt and 52% equity. NGD also settled on an adjustment for the South Louisiana Rider RSP of $2.5 million, with an authorized ROE of 9.95% and a capital structure of 48% debt and 52% equity. The settlements were approved by the LPSC and rates were implemented in July 2016.

Minnesota Rate Case. In August 2015, NGD filed a general rate case with the MPUC requesting an annual increase of $54.1 million.  In September 2015, the MPUC approved an interim increase of $47.8 million in revenues effective October 2, 2015, subject to a refund. The MPUC order was issued in June 2016 authorizing a $27.5 million rate adjustment based on an ROE of 9.49% and an ROR of 7.07%. On June 23, 2016, NGD filed a request for reconsideration. The MPUC has 60 days to take action or the reconsideration request is deemed denied by operation of law. The interim rate refund and final rates can only be implemented after the required compliance filing is accepted by the MPUC.

Minnesota CIP.  In May 2016, NGD filed a CIP request with the MPUC, seeking a $12.7 million financial incentive based on 2015 program performance.  This request is currently pending approval from the MPUC and will be recognized when approved.

Mississippi RRA.  In April 2016, NGD filed for a $3.5 million RRA with the MPSC, which was subsequently revised to a $3.3 million RRA with an adjusted ROE of 9.47%.  The filing is currently pending approval from the MPSC.  New rates are expected to be implemented in the third quarter of 2016.

PHMSA Regulatory Proposals. Recent regulatory proposals from the U.S. Department of Transportation’s PHMSA would expand the scope of its safety, reporting, and recordkeeping requirements for both natural gas and hazardous liquids (including oil and NGLs) pipelines. These proposals, if finalized, would impose additional costs on us and Enable.

In March 2016, PHMSA issued a notice of proposed rulemaking detailing proposed revisions to the safety standards applicable to natural gas transmission and gathering pipelines. The proposed rules would add requirements for pipelines already subject to

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integrity management requirements, including repair criteria for pipelines in high consequence areas and requirements for monitoring gas quality and managing corrosion. For pipelines not already subject to integrity management requirements, the proposed rules include a new moderate consequence area definition, require gas quality monitoring and corrosion management, establish repair criteria and require verification of certain pipeline parameters. The proposed rules would also expand the scope of gas gathering lines subject to PHMSA regulation-including imposing minimum safety standards on certain larger, currently exempt, gathering lines-while subjecting all gathering-line operators to recordkeeping and annual reporting requirements from which they are currently exempt. The rules would also require inspections of pipeline areas affected by severe weather, natural disasters or similar events.

PHMSA issued a similar notice of proposed rulemaking for hazardous liquid pipelines in October 2015. The proposed rules would extend PHMSA reporting requirements to all gathering lines, require pipeline inspections in areas affected by extreme weather or natural disasters, require periodic inline inspections of pipelines outside of high consequence areas, require use of leak detection systems on all hazardous liquid pipelines, modify applicable repair criteria and set a timeline for pipelines subject to integrity management requirements to be capable of accommodating inline inspection tools.

Other Matters

Debt Financing Transaction

InMay 2016, Houston Electric issued $300 million aggregate principal amount of 1.85% general mortgage bonds due 2021. The proceeds from the issuance of the bonds were used to repay short-term debt and for general corporate purposes.

Credit Facilities

Our revolving credit facilities may be drawn on by the companies from time to time to provide funds used for general corporate purposes and to backstop the companies’ commercial paper programs. The facilities may also be utilized to obtain letters of credit. As of July 29, 2016, we had the following facilities:

Execution Date	Company	Size of Facility		Amount Utilized at July 29, 2016 (1)			Termination Date
		(in millions)
March 3, 2016	CenterPoint Energy	$	1,600	$	1,013	(2)	March 3, 2021
March 3, 2016	Houston Electric	300		4		(3)	March 3, 2021
March 3, 2016	CERC Corp.	600		221		(4)	March 3, 2021

(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 $2.5 billion as of June 30, 2016.

(2) Represents outstanding commercial paper of $1,007 million and outstanding letters of credit of $6 million.

(3) Represents outstanding letters of credit.

(4) Represents outstanding commercial paper of $217 million and outstanding letters of credit of $4 million.

Our $1.6 billion revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CenterPoint Energy’s current credit ratings. The revolving credit facility contains a financial covenant which limits our consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of our consolidated capitalization. As of June 30, 2016, our debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 55.5%. 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 we certify to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-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 we deliver our certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of our certification or (iii) the revocation of such certification.

Houston Electric’s $300 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.125% based on Houston Electric’s current credit ratings. The revolving credit facility contains a financial covenant which limits Houston Electric’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to

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an amount not to exceed 65% of Houston Electric’s consolidated capitalization. As of June 30, 2016, Houston Electric’s debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 52.7%. 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 Houston Electric certifies to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-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 Houston Electric delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of Houston Electric’s certification or (iii) the revocation of such certification.

CERC Corp.’s $600 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CERC Corp.’s current credit ratings. The revolving credit facility contains a financial covenant which limits CERC’s consolidated debt to an amount not to exceed 65% of CERC’s consolidated capitalization. As of June 30, 2016, CERC’s debt to capital ratio, as defined in its credit facility agreement, was 30.7%.

Borrowings under each of the three revolving credit facilities are subject to customary terms and conditions. However, there is no requirement that the borrower make representations prior to borrowings 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.

On April 4, 2016, in connection with the replacement of our $1.2 billion unsecured revolving credit facility with the new $1.6 billion facility, we increased the size of our commercial paper program to permit the issuance of commercial paper notes in an aggregate principal amount not to exceed the unused portion of our $1.6 billion facility. The size of CERC Corp.’s commercial paper program will remain at $600 million. Our $1.6 billion revolving credit facility backstops our $1.6 billion commercial paper program. CERC Corp.’s $600 million revolving credit facility backstops its $600 million commercial paper program.

Securities Registered with the SEC

CenterPoint Energy, Houston Electric and CERC Corp. have 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.

Temporary Investments

As of July 29, 2016, we had no temporary external investments.

Money Pool

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.

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Impact on Liquidity of a Downgrade in Credit Ratings

The interest on borrowings under our credit facilities is based on our credit rating. As of July 29, 2016, Moody’s, S&P and Fitch had assigned the following credit ratings to senior debt of CenterPoint Energy and certain subsidiaries: 

	Moody’s		S&P		Fitch
Company/Instrument	Rating	Outlook (1)	Rating	Outlook (2)	Rating	Outlook (3)
CenterPoint Energy Senior Unsecured Debt	Baa1	Stable	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	Stable

(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 rating outlook assesses the potential direction of a long-term credit rating over the intermediate to longer term.

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

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 from Moody’s or S&P could increase borrowing costs under our $1.6 billion revolving credit facility, Houston Electric’s $300 million revolving credit facility and CERC Corp.’s $600 million revolving credit facility. If our credit ratings or those of Houston Electric or CERC Corp. had been downgraded one notch by Moody’s and/or S&P from the ratings that existed at June 30, 2016, 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 our 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 our Natural Gas Distribution and Energy Services business segments.

CERC Corp. and its subsidiaries purchase natural gas from one of their suppliers under supply agreements that contain an aggregate credit threshold of $140 million based on CERC Corp.’s S&P senior unsecured long-term debt rating of A-. Under these agreements, CERC may need to provide collateral if the aggregate threshold is exceeded or if the credit threshold is decreased due to a credit rating downgrade.

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 central and eastern 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 in excess of the credit threshold is routinely collateralized by CES. As of June 30, 2016, the amount posted as collateral aggregated approximately $22 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, 2016, unsecured credit limits extended to CES by counterparties aggregated $367 million, and $2 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 $158 million as of June 30, 2016. The amount of collateral will depend on seasonal variations in transportation levels.

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ZENS and Securities Related to ZENS

In September 1999, we issued ZENS having an original principal amount of $1.0 billion of which $828 million remains outstanding as of June 30, 2016. Each ZENS note 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 note are adjusted for certain corporate events. As of June 30, 2016, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.0625 share of Time Common and 0.061382 share of Charter Common, and the contingent principal amount was $519 million.

On May 26, 2015, Charter announced that it had entered into a definitive merger agreement with TWC. On September 21, 2015, Charter shareholders approved the announced transaction with TWC. Pursuant to the merger agreement, upon closing of the merger, TWC Common would be exchanged for cash and Charter Common and as a result, reference shares for the ZENS would consist of Charter Common, TW Common and Time Common. The merger closed on May 18, 2016. For further information regarding the Charter merger, see Note 11 to our Interim Condensed Financial Statements.

If our creditworthiness were to drop such that ZENS note holders thought our liquidity was adversely affected or the market for the ZENS notes were to become illiquid, some ZENS note holders might decide to exchange their ZENS notes for cash. Funds for the payment of cash upon exchange could be obtained from the sale of the shares of TW Common, Charter Common and Time Common that we own or from other sources. We own shares of TW Common, Charter Common and Time Common equal to approximately 100% of the reference shares used to calculate our obligation to the holders of the ZENS notes. ZENS note exchanges result in a cash outflow because tax deferrals related to the ZENS notes and TW Common, Charter Common and Time Common shares would typically cease when ZENS notes are exchanged or otherwise retired and TW Common, Charter Common and Time Common shares are sold. The ultimate tax liability related to the ZENS notes 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 notes. If all ZENS notes had been exchanged for cash on June 30, 2016, deferred taxes of approximately $501 million would have been payable in 2016. If all the TW Common, Charter Common and Time Common had been sold on June 30, 2016, capital gains taxes of approximately $212 million would have been payable in 2016.

Cross Defaults

Under our 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 us or any of our significant subsidiaries will cause a default. A default by CenterPoint Energy would not trigger a default under our 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.

Enable Midstream Partners

On January 28, 2016, we entered into a purchase agreement with Enable pursuant to which we agreed to purchase in a Private Placement an aggregate of 14,520,000 Series A Preferred Units for a cash purchase price of $25.00 per Series A Preferred Unit. The Private Placement closed on February 18, 2016. In connection with the Private Placement, Enable redeemed approximately $363 million of notes scheduled to mature in 2017 payable to a wholly-owned subsidiary of CERC Corp. We used the proceeds from this redemption for our investment in the Series A Preferred Units.

Enable is expected to pay a minimum quarterly distribution of $0.2875 per 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 (referred to as “available cash”) within 60 days after the end of each quarter. On August 2, 2016, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common and subordinated units for the quarter ended June 30, 2016. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million

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from Enable in the third quarter of 2016 to be made with respect to CERC Corp.’s limited partner interest in Enable for the second quarter of 2016.

On August 2, 2016, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended June 30, 2016. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the third quarter of 2016 to be made with respect to CenterPoint Energy’s investment in Series A Preferred Units of Enable for the second quarter of 2016.

Hedging of Interest Expense for Future Debt Issuances

In April 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $150 million. These agreements were executed to hedge, in part, volatility in the 5-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows related to interest payments of Houston Electric’s $300 million issuance of fixed rate debt in May 2016. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the ineffective portion of unrealized gains and losses associated with the agreements was recorded in income and was immaterial.

In June and July 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $300 million. These agreements were executed to hedge, in part, volatility in the 10-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows relating to interest payments on a forecasted issuance of fixed rate debt in 2016.  These forward interest rate agreements were designated as cash flow hedges.  As of June 30, 2016, a $2 million current non-trading derivative liability was recorded on the Condensed Consolidated Balance Sheets related to these agreements. Accordingly, the effective portion of unrealized gains and losses associated with the agreements would be recorded as a component of accumulated other comprehensive income and the ineffective portion would be recorded in income.

Weather Hedge

We 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 our other jurisdictions. As a result, fluctuations from normal weather may have a positive or negative effect on NGD’s results in Texas and on Houston Electric’s results in its service territory. We have historically entered into heating-degree day swaps for certain NGD jurisdictions to mitigate the effect of fluctuations from normal weather on its results of operations and cash flows for the winter heating season. However, NGD did not enter into heating-degree day swaps for the 2015–2016 winter season as a result of NGD’s Minnesota division implementing a full decoupling pilot in July 2015.  We entered into a weather hedge swap pursuant to the Dodd-Frank’s end-user exception for Houston Electric’s service territory for the 2015–2016 winter season.

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 our weather hedging arrangements, and gas purchases, gas price and gas storage activities of our 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 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 to satisfy their obligations in respect of GenOn’s indemnity obligations to us and our subsidiaries or in connection with the contractual obligations to a third party pursuant to which our subsidiary is their guarantor;

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• the ability of REPs, including REP affiliates of NRG and Energy Future Holdings Corp., to satisfy their obligations to us and our subsidiaries;

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

• the outcome of litigation brought by and against us;

• 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 our 2015 Form 10-K.

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

Houston Electric’s revolving credit facility limits Houston Electric’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of its consolidated capitalization. CERC Corp.’s revolving credit facility limits CERC’s consolidated debt to an amount not to exceed 65% of its consolidated capitalization. Our revolving credit facility limits our consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of our consolidated capitalization. The financial covenant limit in Houston Electric’s and our revolving credit facilities will temporarily increase from 65% to 70% if Houston Electric experiences damage from a natural disaster in its service territory that meets certain criteria. Additionally, Houston Electric has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 2 to our Interim Condensed Consolidated Financial Statements for a discussion of new accounting pronouncements that affect us.

Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

As of June 30, 2016, we had outstanding long-term debt, bank loans, lease obligations and obligations under our ZENS (indexed debt securities) that subject us to the risk of loss associated with movements in market interest rates.

As of June 30, 2016 and December 31, 2015, our floating-rate obligations aggregated $1.2 billion and $1.1 billion, respectively. If the floating interest rates were to increase by 10% from June 30, 2016 rates, our combined interest expense would increase by approximately $1 million annually.

As of June 30, 2016 and December 31, 2015, we had outstanding fixed-rate debt (excluding indexed debt securities) aggregating $7.3 billion and $7.5 billion, respectively, in principal amount and having a fair value of $8.1 billion and $8.0 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 $193 million if interest rates were to decline by 10% from their levels at June 30, 2016. 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 $111 million as of June 30, 2016 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 $20 million if interest rates were to decline by 10% from levels at June 30, 2016. Changes in the fair value of the derivative component, a liability recorded at $490 million as of June 30, 2016, 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 risk-free interest rate. If the risk-free interest rate were to increase by 10% from June 30, 2016 levels, the fair value of the derivative component would increase by approximately $2 million, which would be recorded as an unrealized loss in our Condensed Statements of Consolidated Income.

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Equity Market Value Risk

We are exposed to equity market value risk through our ownership of 7.1 million shares of TW Common, 0.9 million shares of Time Common and 0.9 million shares of Charter Common, which we hold to facilitate our ability to meet our obligations under the ZENS. A decrease of 10% from the June 30, 2016 aggregate market value of these shares would result in a net loss of approximately $7 million, which would be recorded as an unrealized loss in our Condensed Statements of Consolidated Income.

Commodity Price Risk From Non-Trading Activities

We use derivative instruments as economic hedges to offset the commodity price exposure inherent in our businesses. The stand-alone commodity risk created by these instruments, without regard to the offsetting effect of the underlying exposure these instruments are intended to hedge, is described below. We measure the commodity risk of our non-trading energy derivatives using a sensitivity analysis. The sensitivity analysis performed on our non-trading energy derivatives measures the potential loss in fair value based on a hypothetical 10% movement in energy prices. As of June 30, 2016, the recorded fair value of our non-trading energy derivatives was a net asset of $46 million (before collateral), all of which is related to our Energy Services business segment. An increase of 10% in the market prices of energy commodities from their June 30, 2016 levels would have decreased the fair value of our non-trading energy derivatives net asset by $9 million.

The above analysis of the non-trading energy derivatives utilized for commodity price risk management purposes does not include the favorable impact that the same hypothetical price movement would have on our non-derivative physical purchases and sales of natural gas to which the hedges relate. Furthermore, the non-trading energy derivative portfolio is managed to complement the physical transaction portfolio, reducing overall risks within limits. Therefore, the adverse impact to the fair value of the portfolio of non-trading energy derivatives held for hedging purposes associated with the hypothetical changes in commodity prices referenced above is expected to be substantially offset by a favorable impact on the underlying hedged physical transactions.

Item 4. CONTROLS AND PROCEDURES

In accordance with Exchange Act Rules 13a-15 and 15d-15, we carried out an evaluation, under the supervision and with the participation of management, including our principal executive officer and principal financial officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of June 30, 2016 to provide assurance that information required to be disclosed in our reports filed or submitted under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding disclosure.

There has been no change in our internal controls over financial reporting that occurred during the three months ended June 30, 2016 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

PART II. OTHER INFORMATION

Item 1. LEGAL PROCEEDINGS

For a description of certain legal and regulatory proceedings affecting CenterPoint Energy, please read Note 14(b) to our 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 our 2015 Form 10-K.

Item 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in our 2015 Form 10-K.

Item 5. OTHER INFORMATION

Ratio of Earnings to Fixed Charges. The ratio of earnings to fixed charges for the six months ended June 30, 2016 and 2015 was 2.35 and 2.53, respectively. We do not believe that the ratios for these six-month periods are necessarily indicative of the ratios for the twelve-month periods due to the seasonal nature of our business. The ratios were calculated pursuant to applicable rules of the SEC.

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Item 6. EXHIBITS

The following exhibits are filed herewith:

Exhibits not incorporated by reference to a prior filing 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 CenterPoint Energy, Inc., any other persons, any state of affairs or other matters.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, CenterPoint Energy has 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 CenterPoint Energy and its subsidiaries on a consolidated basis. CenterPoint Energy hereby agrees 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
3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2
3.2	Second Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2015	1-31447	3(b)
3.3	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)
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1
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
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
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
+4.5	Twenty-Fourth Supplemental Indenture, dated as of May 18, 2016, to the General Mortgage Indenture, dated as of October 10, 2002, between Houston Electric and the Trustee
+4.6	Officer’s Certificate, dated as of May 18, 2016, setting forth the form, terms and provisions of the Twenty-Fifth Series of General Mortgage Bonds
10.1	Fourth Amended and Restated Agreement of Limited Partnership of Enable Midstream Partners, LP, dated June 22, 2016	CenterPoint Energy’s Form 8-K dated June 22, 2016	1-31447	10.1
10.2	Third Amended and Restated Limited Liability Company Agreement of Enable GP, LLC, dated June 22, 2016	CenterPoint Energy’s Form 8-K dated June 22, 2016	1-31447	10.2
+12	Computation of Ratios of Earnings to Fixed Charges
+31.1	Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka
+31.2	Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers
+32.1	Section 1350 Certification of Scott M. Prochazka
+32.2	Section 1350 Certification of William D. Rogers

44

Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference
+101.INS	XBRL Instance Document
+101.SCH	XBRL Taxonomy Extension Schema Document
+101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
+101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
+101.LAB	XBRL Taxonomy Extension Labels Linkbase Document
+101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

45

SIGNATURES

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

	CENTERPOINT ENERGY, INC.
By:	/s/ Kristie L. Colvin
	Kristie L. Colvin
	Senior Vice President and Chief Accounting Officer

Date: August 5, 2016

46

Index to Exhibits

The following exhibits are filed herewith:

Exhibits not incorporated by reference to a prior filing 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 CenterPoint Energy, Inc., any other persons, any state of affairs or other matters.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, CenterPoint Energy has 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 CenterPoint Energy and its subsidiaries on a consolidated basis. CenterPoint Energy hereby agrees 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
3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2
3.2	Second Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2015	1-31447	3(b)
3.3	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)
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1
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
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
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
+4.5	Twenty-Fourth Supplemental Indenture, dated as of May 18, 2016, to the General Mortgage Indenture, dated as of October 10, 2002, between Houston Electric and the Trustee
+4.6	Officer’s Certificate, dated as of May 18, 2016, setting forth the form, terms and provisions of the Twenty-Fifth Series of General Mortgage Bonds
10.1	Fourth Amended and Restated Agreement of Limited Partnership of Enable Midstream Partners, LP, dated June 22, 2016	CenterPoint Energy’s Form 8-K dated June 22, 2016	1-31447	10.1
10.2	Third Amended and Restated Limited Liability Company Agreement of Enable GP, LLC, dated June 22, 2016	CenterPoint Energy’s Form 8-K dated June 22, 2016	1-31447	10.2
+12	Computation of Ratios of Earnings to Fixed Charges
+31.1	Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka
+31.2	Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers
+32.1	Section 1350 Certification of Scott M. Prochazka
+32.2	Section 1350 Certification of William D. Rogers

47

Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference
+101.INS	XBRL Instance Document
+101.SCH	XBRL Taxonomy Extension Schema Document
+101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
+101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
+101.LAB	XBRL Taxonomy Extension Labels Linkbase Document
+101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

48

EX-4.5

Exhibit 4.5

CenterPoint Energy Houston Electric, LLC 1111 Louisiana

Houston, TX 77002

=====================================================================

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC TO

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION

(successor in trust to JPMORGAN CHASE BANK),

as Trustee

----------

TWENTY-FOURTH SUPPLEMENTAL INDENTURE

Dated as of May 18, 2016

----------

Supplementing the General Mortgage Indenture Dated as of October 10, 2002

Filed under file number 030004510538 in the Office of the Secretary of State as an instrument granting a security interest by a public utility

THIS INSTRUMENT GRANTS A SECURITY INTEREST BY A UTILITY THIS INSTRUMENT CONTAINS AFTER-ACQUIRED PROPERTY PROVISIONS

This instrument is being filed pursuant to Chapter 261 of the Texas Business and Commerce Code

=====================================================================

TWENTY-FOURTH SUPPLEMENTAL INDENTURE, dated as of May 18, 2016, between CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC, a limited liability company organized and existing under the laws of the State of Texas (herein called the “Company”), having its principal office at 1111 Louisiana, Houston, Texas 77002, and THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION (successor in trust to JPMORGAN CHASE BANK), a limited purpose national banking association duly organized and existing under the laws of the United States, as Trustee (herein called the “Trustee”), the office of the Trustee at which on the date hereof its corporate trust business is administered being 601 Travis Street, 16th Floor, Houston, Texas 77002.

RECITALS OF THE COMPANY

WHEREAS, the Company has heretofore executed and delivered to the Trustee a General Mortgage Indenture dated as of October 10, 2002, as supplemented and amended (the “Indenture”), providing for the issuance by the Company from time to time of its bonds, notes or other evidence of indebtedness to be issued in one or more series (in the Indenture and herein called the “Securities”) and to provide security for the payment of the principal of and premium, if any, and interest, if any, on the Securities; and

WHEREAS, the Company, in the exercise of the power and authority conferred upon and reserved to it under the provisions of the Indenture and pursuant to appropriate resolutions of the Manager, has duly determined to make, execute and deliver to the Trustee this Twenty-Fourth Supplemental Indenture to the Indenture as permitted by Sections 201, 301, 403(2) and 1401 of the Indenture in order to establish the form or terms of, and to provide for the creation and issuance of, a twenty-fifth series of Securities under the Indenture in an initial aggregate principal amount of $300,000,000 (such twenty-fifth series being hereinafter referred to as the “Twenty-Fifth Series”); and

WHEREAS, all things necessary to make the Securities of the Twenty-Fifth Series, when executed by the Company and authenticated and delivered by the Trustee or any Authenticating Agent and issued upon the terms and subject to the conditions hereinafter and in the Indenture set forth against payment therefor the valid, binding and legal obligations of the Company and to make this Twenty-Fourth Supplemental Indenture a valid, binding and legal agreement of the Company, have been done;

NOW, THEREFORE, THIS TWENTY-FOURTH SUPPLEMENTAL INDENTURE WITNESSETH that, in order to establish the terms of a series of Securities, and for and in consideration of the premises and of the covenants contained in the Indenture and in this Twenty-Fourth Supplemental Indenture and for other good and valuable consideration the receipt and sufficiency of which are hereby acknowledged, it is mutually covenanted and agreed as follows:

ARTICLE ONE

DEFINITIONS AND OTHER PROVISIONS OF GENERAL APPLICATION

Section 101. Definitions. Each capitalized term that is used herein and is defined in the Indenture shall have the meaning specified in the Indenture unless such term is otherwise defined herein.

ARTICLE TWO

TITLE, FORM AND TERMS OF THE BONDS

Section 201. Title of the Bonds. This Twenty-Fourth Supplemental Indenture hereby creates a series of Securities designated as the “1.85% General Mortgage Bonds, Series Y, due 2021” (the “Series Y Bonds”). For purposes of the Indenture, the Series Y Bonds shall constitute a single series of Securities and, subject to the provisions, including, but not limited to Article Four of the Indenture, the Series Y Bonds shall be issued in an aggregate principal amount of $300,000,000.

Section 202. Form and Terms of the Bonds. The form and terms of the Series Y Bonds will be set forth in an Officer’s Certificate delivered by the Company to the Trustee pursuant to the authority granted by this Twenty-Fourth Supplemental Indenture in accordance with Sections 201 and 301 of the Indenture.

Section 203. Treatment of Proceeds of Title Insurance Policy. Any moneys received by the Trustee as proceeds of any title insurance policy on Mortgaged Property of the Company shall be subject to and treated in accordance with the provisions of Section 607(2) of the Indenture (other than the last paragraph thereof).

ARTICLE THREE MISCELLANEOUS PROVISIONS

The Trustee makes no undertaking or representations in respect of, and shall not be responsible in any manner whatsoever for and in respect of, the validity or sufficiency of this Twenty-Fourth Supplemental Indenture or the proper authorization or the due execution hereof by the Company or for or in respect of the recitals and statements contained herein, all of which recitals and statements are made solely by the Company.

Except as expressly amended and supplemented hereby, the Indenture shall continue in full force and effect in accordance with the provisions thereof and the Indenture is in all respects hereby ratified and confirmed. This Twenty-Fourth Supplemental Indenture and all of its provisions shall be deemed a part of the Indenture in the manner and to the extent herein and therein provided.

This Twenty-Fourth Supplemental Indenture shall be governed by, and construed in accordance with, the law of the State of New York.

2

This Twenty-Fourth Supplemental Indenture may be executed in any number of counterparts, each of which so executed shall be deemed to be an original, but all such counterparts shall together constitute but one and the same instrument.

3

IN WITNESS WHEREOF, the parties hereto have caused this Twenty-Fourth Supplemental Indenture to be duly executed as of the day and year set forth below and effective as of the day and year first above written.

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
Dated: May 18, 2016	By:	/s/ Kristie L. Colvin
	Name:	Kristie L. Colvin
	Title:	Senior Vice President and Chief Accounting Officer
THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION (successor in trust to JPMORGAN CHASE BANK), as Trustee
Dated: May 18, 2016	By:	/s/ Manjari Purkayastha
	Name:	Manjari Purkayastha
	Title:	Vice President

ACKNOWLEDGMENT

STATE OF TEXAS	)
	)	ss
COUNTY OF HARRIS	)

On the 18th day of May, 2016, before me personally came Kristie L. Colvin, to me known, who, being by me duly sworn, did depose and say that she resides in Katy, Texas; that she is the Senior Vice President and Chief Accounting Officer of CenterPoint Energy Houston Electric, LLC, a Texas limited liability company, the limited liability company described in and which executed the foregoing instrument; and that she signed her name thereto by authority of the sole manager of said limited liability company.

/s/ Alida E. Duggan

Notary Public

4

ACKNOWLEDGMENT

State of California County of Los Angeles )

On May 17, 2016 before me,	Alex Dominguez, Notary Public
	(insert name and title of the officer)

personally appeared Manjari Purkayastha, who proved to me on the basis of satisfactory evidence to be the person(s) whose name(s) is/are subscribed to the within instrument and acknowledged to me that he/she/they executed the same in his/her/their authorized capacity(ies), and that by

his/her/their signature(s) on the instrument the person(s), or the entity upon behalf of which the person(s) acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California that the foregoing paragraph is true and correct.

WITNESS my hand and official seal.

Signature    /s/ Alex Dominguez    (Seal)

EX-4.6

Exhibit 4.6

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC OFFICER’S CERTIFICATE

May 18, 2016

I, the undersigned officer of CenterPoint Energy Houston Electric, LLC, a Texas limited liability company (the “Company”), do hereby certify that I am an Authorized Officer of the Company as such term is defined in the Indenture (as defined herein). I am delivering this certificate pursuant to the authority granted in the Resolutions adopted by written consent of the sole Manager of the Company dated May 6, 2016, and Sections 105, 201, 301, 401(1), 401(5), 403(2)(B) and 1403 of the General Mortgage Indenture, dated as of October 10, 2002, as heretofore supplemented to the date hereof (as heretofore supplemented, the “Indenture”), between the Company and The Bank of New York Mellon Trust Company, National Association (successor in trust to JPMorgan Chase Bank), as Trustee (the “Trustee”). Terms used herein and not otherwise defined herein shall have the meanings assigned to them in the Indenture, unless the context clearly requires otherwise. Based upon the foregoing, I hereby certify on behalf of the Company as follows:

1.The terms and conditions of the Securities of the series described in this Officer’s Certificate are as follows (the numbered subdivisions set forth in this Paragraph 1 corresponding to the numbered subdivisions of Section 301 of the Indenture):

(1)The Securities of the twenty-fifth series to be issued under the Indenture shall be designated as the “1.85% General Mortgage Bonds, Series Y, due 2021” (the “Bonds”), as set forth in the Twenty-Fourth Supplemental Indenture, dated as of the date hereof, between the Company and the Trustee.

(2)The Trustee shall authenticate and deliver the Bonds for original issue on May 18, 2016 (the “Issue Date”) in the aggregate principal amount of $300,000,000, upon a Company Order for the authentication and delivery thereof and satisfaction of Section 401 of the Indenture.

(3)Interest on the Bonds shall be payable to the Persons in whose names such Securities are registered at the close of business on the Regular Record Date for such interest (as specified in (5) below), except as otherwise expressly provided in the form of such Securities attached hereto as Exhibit A.

(4)The Bonds shall mature and the principal thereof shall be due and payable together with all accrued and unpaid interest thereon on June 1, 2021.

(5)The Bonds shall bear interest at the rate of 1.85% per annum. Interest shall accrue on the Bonds from the Issue Date, or the most recent date to which interest has been paid or duly provided for. The Interest Payment Dates for the Bonds shall be June 1 and December 1 in each year commencing December 1, 2016, and the Regular Record Dates with respect to the Interest Payment Dates for the Bonds shall be the May 15 and November 15, respectively, immediately preceding each Interest Payment Date (whether or not a Business Day); provided however that interest payable at maturity, upon redemption or when principal is otherwise due will be payable to the Holder to whom principal is payable.

(6)The Corporate Trust Office of The Bank of New York Mellon Trust Company, National Association in New York, New York shall be the place at which (i) the principal of and premium, if any, and interest on the Bonds shall be payable, (ii) registration of transfer of the Bonds may be effected, (iii) exchanges of the Bonds may be effected, and(iv) notices and demands to or upon the Company in respect of the Bonds and the Indenture may be served; and The Bank of New York Mellon Trust Company, National Association shall be the Security Registrar and Paying Agent for the Bonds; provided, however, that the Company reserves the right to change, by one or more Officer’s Certificates, any such place or the Security Registrar; and provided, further, that the Company reserves the right to designate, by one or more Officer’s Certificates, its principal office in Houston, Texas as any such place or itself as the Security Registrar; provided, however, that there shall be only a single Security Registrar for each series of Bonds.

(7)The Bonds shall be redeemable, at the option of the Company, at any time or from time to time, in whole or in part, on any date prior to May 1, 2021 at a price equal to the greater of (i) 100% of the principal amount of the Bonds to be redeemed or (ii) the sum of the present values of the remaining scheduled payments of principal and interest on the Bonds to be redeemed that would be due if the Bonds matured on May 1, 2021 but for the redemption (not including any portion of such payments of interest accrued to the Redemption Date) discounted to the date of redemption (the “Redemption Date”) on a semiannual basis (assuming a 360-day year consisting of twelve 30-day months) at the applicable Treasury Rate plus 12.5 basis points plus, in each case, accrued and unpaid interest on the principal amount being redeemed to the Redemption Date. On or after May 1, 2021, the Company may redeem the Bonds, at any time or from time to time, in whole or in part, by paying 100% of the principal amount of Bonds to be redeemed plus accrued and unpaid interest on the principal amount being redeemed to the Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated “H.15 (519)” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded U.S. Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the Comparable Treasury Issue (if no maturity is within three months before or after the remaining life (as defined below), yields for the two published maturities most closely corresponding to the Comparable Treasury Issue will be

2

determined and the Treasury Rate will be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month); or if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated by the Independent Investment Banker using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate will be calculated by the Independent Investment Banker on the third Business Day preceding the Redemption Date.

“Comparable Treasury Issue” means the U.S. Treasury security selected by an Independent Investment Banker as having an actual or interpolated maturity comparable to the remaining term (“remaining life”) of the Bonds to be redeemed (assuming for this purpose that the Bonds matured on May 1, 2021) that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such Bonds.

“Comparable Treasury Price” means (1) the average of four Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (2) if the Independent Investment Banker obtains fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC or Wells Fargo Securities, LLC, as specified by the Company, or if these firms are unwilling or unable to select the Comparable Treasury Issue, an independent investment banking institution of national standing selected by the Company.

“Reference Treasury Dealer” means each of (1) Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Wells Fargo Securities, LLC, and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States of America (a “Primary Treasury Dealer”), the Company will substitute therefor another Primary Treasury Dealer and (2) any other Primary Treasury Dealer selected by the Company after consultation with the Independent Investment Banker.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 5:00 p.m., New York City time, on the third business day preceding such Redemption Date.

The Trustee, at the written direction of the Company, will send a notice of redemption to each holder of Bonds to be redeemed by first-class mail (or in accordance with the procedures of The Depository Trust Company with respect to Bonds registered in the name of Cede & Co.) at least 30 and not more than 60 days prior to the date fixed for redemption. Unless the Company defaults on payment of the redemption price, interest will cease to accrue on the Bonds or portions thereof called for redemption on the

3

Redemption Date. If fewer than all of the Bonds are to be redeemed, the Trustee will select, not more than 60 days prior to the Redemption Date, the particular Bonds or portions thereof for redemption from the outstanding Bonds not previously called by such method as the Trustee deems fair and appropriate. The Trustee may select for redemption Bonds and portions of Bonds in amounts of $1,000 or whole multiples of $1,000. In the case of a partial redemption of Bonds registered in the name of Cede & Co, the Bonds to be redeemed will be determined in accordance with the procedures of The Depository Trust Company.

(8) Not applicable.

(9) Not applicable.

(10) Not applicable.

(11) Not applicable.

(12) Not applicable.

(13) See subsection (7) above.

(14) Not applicable.

(15) Not applicable.

(16) Not applicable.

(17)The Bonds shall be issuable in whole or in part in the form of one or more Global Securities (as defined below). The Depositary Trust Company shall initially serve as Depositary (as defined below) with respect to the Global Securities. “Depositary” means, with respect to Securities of any series issuable in whole or in part in the form of one or more Global Securities, a clearing agency registered under the Exchange Act that is designated to act as depositary for such Securities. “Global Security” means a Security that evidences all or part of the Securities of a series and bears a legend in substantially the following form:

THIS SECURITY IS IN GLOBAL FORM AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE OF A DEPOSITARY. THIS SECURITY IS EXCHANGEABLE FOR SECURITIES REGISTERED IN THE NAME OF A PERSON OTHER THAN THE DEPOSITARY OR ITS NOMINEE ONLY IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE AND MAY NOT BE TRANSFERRED EXCEPT AS A WHOLE BY THE DEPOSITARY TO A NOMINEE OF THE DEPOSITARY OR BY A NOMINEE OF THE DEPOSITARY TO THE DEPOSITARY OR ANOTHER NOMINEE OF THE DEPOSITARY.

The provisions of Clauses (1), (2), (3) and (4) below shall apply only to Global Securities:

(1)Each Global Security authenticated under the Indenture shall be registered in the name of the Depositary designated for such Global Security or a nominee thereof and delivered to such Depositary or a nominee thereof or custodian therefor, and each such Global Security shall constitute a single Security for all purposes of the Indenture.

4

(2)Notwithstanding any other provision in the Indenture, no Global Security may be exchanged in whole or in part for Securities registered, and no transfer of a Global Security in whole or in part may be registered, in the name of any Person other than the Depositary for such Global Security or a nominee thereof unless (A) the Company has notified the Trustee that the Depositary is unwilling or unable to continue as Depositary for such Global Security, the Depositary defaults in the performance of its duties as Depositary, or the Depositary has ceased to be a clearing agency registered under the Exchange Act, in each case, unless the Company has approved a successor Depositary within 90 days, (B) the Company in its sole discretion determines that such Global Security will be so exchangeable or transferable or (C) there shall exist such circumstances, if any, in addition to or in lieu of the foregoing as have been specified for this purpose as contemplated by the Indenture.

(3)Subject to Clause (2) above, any exchange of a Global Security for other Securities may be made in whole or in part, and all Securities issued in exchange for a Global Security or any portion thereof shall be registered in such names as the Depositary for such Global Security shall direct.

(4)Every Security authenticated and delivered upon registration of transfer of, or in exchange for or in lieu of, a Global Security or any portion thereof, whether pursuant to Sections 304, 305, 306, 507 or 1406 of the Indenture or otherwise, shall be authenticated and delivered in the form of, and shall be, a Global Security, unless such Security is registered in the name of a Person other than the Depositary for such Global Security or a nominee thereof.

(18) Not applicable.

(19) Not applicable.

(20)For purposes of the Bonds, “Business Day” shall mean any day, other than Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York, New York.

(21) Not applicable.

(22)The Bonds shall have such other terms and provisions as are provided in the form thereof attached hereto as Exhibit A, and shall be issued in substantially such form.

2.The undersigned has read all of the covenants and conditions contained in the Indenture, and the definitions in the Indenture relating thereto, relating to the issuance of the Bonds and in respect of compliance with which this certificate is made.

3.The statements contained in this certificate are based upon the familiarity of the undersigned with the Indenture, the documents accompanying this certificate, and upon discussions by the undersigned with officers and employees of the Company familiar with the matters set forth herein.

4.In the opinion of the undersigned, she has made such examination or investigation as is necessary to enable him to express an informed opinion as to whether or not such covenants and conditions have been complied with.

5.In the opinion of the undersigned, such conditions and covenants have been complied with.

5

6. To my knowledge, no Event of Default has occurred and is continuing.

7.The execution of the Twenty-Fourth Supplemental Indenture, dated as of the date hereof, between the Company and the Trustee is authorized or permitted by the Indenture.

8.With respect to Section 403(2)(B) of the Indenture, General Mortgage Bonds, due January 1, 2011, having an aggregate principal amount of $19,200,000, General Mortgage Bonds, due June 1, 2026, having an aggregate principal amount of $100,000,000 and General Mortgage Bonds, due January 15, 2014, having an aggregate principal amount of 180,800,000 out of $300,000,000 (collectively, the “Retired Mortgage Bonds”), have heretofore been authenticated and delivered and as of the date of this certificate, constitute Retired Securities.$300,000,000 aggregate principal amount of such Retired Mortgage Bonds are the basis for the authentication and delivery of $300,000,000 aggregate principal amount of the Series Y Bonds.

9. The First Mortgage Collateralization Date has not occurred.

10.No certificate of an Independent Accountant pursuant to Section 104 of the Indenture is required in connection with the authentication and delivery of the Bonds because (i) the Net Earnings Certificate covers a period different from that required to be covered by annual reports required to be filed by the Company and (ii) an Independent Accountant has provided the Company with a letter addressed to the Company containing the results of procedures on financial information included in the Net Earnings Certificate that are agreed upon by the Authorized Officer signing the Net Earnings Certificate.

11.Pursuant to the resolutions adopted by the Sole Manager of the Company by written consent on May 6, 2016, Robert McRae, Assistant Treasurer, has been named an Authorized Officer, as defined under the Indenture, including for purposes of executing the Net Earnings Certificate.

6

IN WITNESS WHEREOF, the undersigned has executed this Officer’s Certificate as of the date first written above.

/s/ Kristie L. Colvin      Kristie L. Colvin

Senior Vice President and Chief Accounting Officer

Acknowledged and Received as of the date first written above

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION,

as Trustee

/s/ Manjari Purkayastha      Manjari Purkayastha

Vice President

EXHIBIT A

FORM OF BONDS

THIS SECURITY IS IN GLOBAL FORM AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE OF A DEPOSITARY. THIS SECURITY IS EXCHANGEABLE FOR SECURITIES REGISTERED IN THE NAME OF A PERSON OTHER THAN THE DEPOSITARY OR ITS NOMINEE ONLY IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE AND MAY NOT BE TRANSFERRED EXCEPT AS A WHOLE BY THE DEPOSITARY TO A NOMINEE OF THE DEPOSITARY OR BY A NOMINEE OF THE DEPOSITARY TO THE DEPOSITARY OR ANOTHER NOMINEE OF THE DEPOSITARY.

Unless this certificate is presented by an authorized representative of The Depository Trust Company, a New York corporation (“DTC”), to CenterPoint Energy Houston Electric, LLC or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC

1.85% General Mortgage Bonds, Series Y, due 2021

Original Interest Accrual Date: May 18, 2016	Redeemable: Yes [X] No [ ]
Stated Maturity: June 1, 2021	Redemption Date: At any time.
Interest Rate: 1.85%	Redemption Price: on any date prior to May 1, 2021 at a price equal to the greater of (i) 100% of the principal amount of this Security or the portion hereof to be redeemed or (ii) the sum of the present values of the remaining scheduled payments of principal and interest on this Security or the portion thereof to be redeemed that would be due if this Security matured on May 1, 2021 but for the redemption (not including any portion of such payments of interest accrued to the Redemption Date) discounted to the Redemption Date on a semiannual basis at the applicable Treasury Rate plus 12.5 basis points; plus, in each case, accrued and unpaid interest to the Redemption Date on the principal amount being redeemed; or on or after May 1, 2021, at a price equal to 100% of the principal amount of this Security or the portion thereof to be redeemed plus accrued and unpaid interest to the Redemption Date on the principal amount being redeemed.
Interest Payment Dates: June 1 and December 1
Regular Record Dates: May 15 and November 15 immediately preceding the respective Interest Payment Date

This Security is not an Original Issue Discount Security within the meaning of the within-mentioned Indenture.

_____________________________

Principal Amount    Registered No. T-1

$300,000,000*    CUSIP 15189X AP3

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC, a limited liability company duly organized and existing under the laws of the State of Texas (herein called the “Company,” which term includes any successor under the Indenture referred to below), for value received, hereby promises to pay to

***CEDE & Co.***

_____________________

*Reference is made to Schedule A attached hereto with respect to decreases and increases in the aggregate principal amount of Securities evidenced hereby.

, or its registered assigns, the principal sum of THREE HUNDRED MILLION DOLLARS, on the Stated Maturity specified above, and to pay interest thereon from the Original Interest Accrual Date specified above or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on the Interest Payment Dates specified above in each year, commencing on December 1, 2016, and at Maturity, at the Interest Rate per annum specified above, until the principal hereof is paid or duly provided for. The interest so payable, and paid or duly provided for, on any Interest Payment Date shall, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date specified above (whether or not a Business Day) next preceding such Interest Payment Date. Notwithstanding the foregoing, interest payable at Maturity shall be paid to the Person to whom principal shall be paid. Except as otherwise provided in said Indenture, any such interest not so paid or duly provided for shall forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice of which shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Payment of the principal of and premium, if any, on this Security and interest hereon at Maturity shall be made upon presentation of this Security at the office of the Corporate Trust Administration of The Bank of New York Mellon Trust Company, National Association, located in New York, New York or at such other office or agency as may be designated for such purpose by the Company from time to time. Payment of interest on this Security (other than interest at Maturity) shall be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register, except that if such Person shall be a securities depositary, such payment may be made by such other means in lieu of check, as shall be agreed upon by the Company, the Trustee and such Person. Payment of the principal of and premium, if any, and interest on this Security, as aforesaid, shall be made in such coin or currency of the United States of America as at the time of payment shall be legal tender for the payment of public and private debts.

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and issuable in one or more series under and equally secured by a General Mortgage Indenture, dated as of October 10, 2002, as supplemented and amended (such Indenture as originally executed and delivered and as supplemented or amended from time to time thereafter, together with any constituent instruments establishing the terms of particular Securities, being herein called the “Indenture”), between the Company and The Bank of New York Mellon Trust Company, National Association (successor in trust to JPMorgan Chase Bank), trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the property mortgaged, pledged and held in trust, the nature and extent of the security and the respective rights, limitations of rights, duties and immunities of the Company, the Trustee and the Holders of the Securities thereunder and of the terms and conditions upon which the Securities are, and are to be, authenticated and delivered and secured. The acceptance of this Security shall be deemed to constitute the consent and agreement by the Holder hereof to all of the terms and provisions of the Indenture. This Security is one of the series designated above.

If any Interest Payment Date, any Redemption Date or the Stated Maturity shall not be a Business Day (as hereinafter defined), payment of the amounts due on this Security on such date may be made on the next succeeding Business Day; and, if such payment is made or duly provided for on such Business Day, no interest shall accrue on such amounts for the period from and after such Interest Payment Date, Redemption Date or Stated Maturity, as the case may be, to such Business Day. Interest will be computed on the basis of a 360-day year of twelve 30-day months.

This Security is subject to redemption, at the option of the Company, at any time or from time to time, in whole or in part, on any date prior to May 1, 2021 at a price equal to the greater of (i) 100% of the principal amount of this Security (or the portion hereof to be redeemed) or (ii) the sum of the present values of the remaining scheduled payments of principal and interest on this Security (or such portion to be redeemed) that would be due if this Security (or such portion to be redeemed) matured on May 1, 2021 but for the redemption (not including any portion of such payments of interest accrued to the Redemption Date) discounted to the Redemption Date on a semiannual

basis (assuming a 360-day year consisting of twelve 30-day months) at the applicable Treasury Rate plus 12.5 basis points; plus, in each case, accrued and unpaid interest on the principal amount being redeemed to the Redemption Date. On or after May 1, 2021, the Company may redeem this Security, at any time or from time to time, in whole or in part, by paying 100% of the principal amount of this Security (or such portion to be redeemed) plus accrued and unpaid interest on the principal amount being redeemed to the Redemption Date. The Trustee shall have no responsibility for the calculation of such amount.

“Treasury Rate” means, with respect to any Redemption Date the yield under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated “H.15 (519)” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded U.S. Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the Comparable Treasury Issue (if no maturity is within three months before or after the remaining life (as defined below), yields for the two published maturities most closely corresponding to the Comparable Treasury Issue will be determined and the Treasury Rate will be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month); or if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated by the Independent Investment Banker using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate will be calculated by the Independent Investment Banker on the third Business Day preceding the Redemption Date.

“Comparable Treasury Issue” means the U.S. Treasury security selected by an Independent Investment Banker as having an actual or interpolated maturity comparable to the remaining term (“remaining life”) of this Security to be redeemed (assuming for this purpose that this Security matured on May 1, 2021) that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of this Security.

“Comparable Treasury Price” means (1) the average of four Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (2) if the Independent Investment Banker obtains fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC or Wells Fargo Securities, LLC, in each case as specified by the Company, or if these firms are unwilling or unable to select the Comparable Treasury Issue, an independent investment banking institution of national standing selected by the Company.

“Reference Treasury Dealer” means each of (1) Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Wells Fargo Securities, LLC and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States of America (a “Primary Treasury Dealer”), the Company will substitute therefor another Primary Treasury Dealer and (2) any other Primary Treasury Dealer selected by the Company after consultation with the Independent Investment Banker.

“Reference Treasury Dealer Quotations” means with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

The Trustee, at the written direction of the Company, will send a notice of redemption to each Holder of Securities to be redeemed by first-class mail (or in accordance with the procedures of The Depository Trust Company with respect to Securities registered in the name of Cede & Co.) at least 30 and not more than 60 days prior to the date fixed for redemption. Unless the Company defaults on payment of the redemption price, interest will cease to accrue on the Securities or portions thereof called for redemption on the Redemption Date. If fewer than all of the Securities of this series are to be redeemed, the Trustee will select, not more than 60 days prior to the Redemption

Date, the particular Securities of this series or portions thereof for redemption from the outstanding Securities of this series not previously called by such method as the Trustee deems fair and appropriate. The Trustee may select for redemption Securities of this series and portions of Securities of this series in amounts of $1,000 or whole multiples of $1,000. In the case of a partial redemption of Securities registered in the name of Cede & Co, the Securities to be redeemed will be determined in accordance with the procedures of The Depository Trust Company.

The Indenture permits, with certain exceptions as therein provided, the Trustee to enter into one or more supplemental indentures for the purpose of adding any provisions to, or changing in any manner or eliminating any of the provisions of, the Indenture with the consent of the Holders of not less than a majority in aggregate principal amount of the Securities of all series then Outstanding under the Indenture, considered as one class; provided, however, that if there shall be Securities of more than one series Outstanding under the Indenture and if a proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such series, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all series so directly affected, considered as one class, shall be required; and provided, further, that if the Securities of any series shall have been issued in more than one Tranche and if the proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such Tranches, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all Tranches so directly affected, considered as one class, shall be required; and provided, further, that the Indenture permits the Trustee to enter into one or more supplemental indentures for limited purposes without the consent of any Holders of Securities. The Indenture also contains provisions permitting the Holders of a majority in principal amount of the Securities then Outstanding, on behalf of the Holders of all Securities, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in the Indenture and subject to certain limitations therein set forth, this Security or any portion of the principal amount hereof will be deemed to have been paid for all purposes of the Indenture and to be no longer Outstanding thereunder, and, at the election of the Company, the Company’s entire indebtedness in respect thereof will be satisfied and discharged, if there has been irrevocably deposited with the Trustee or any Paying Agent (other than the Company), in trust, money in an amount which will be sufficient and/or Eligible Obligations, the principal of and interest on which when due, without regard to any reinvestment thereof, will provide moneys which, together with moneys so deposited, will be sufficient to pay when due the principal of and interest on this Security when due.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the Corporate Trust Office of The Bank of New York Mellon Trust Company, National Association in New York, New York, or such other office or agency as may be designated by the Company from time to time, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series of authorized denominations and of like tenor and aggregate principal amount, will be issued to the designated transferee or transferees.

The Securities of this series are issuable only as registered Securities, without coupons, and in denominations of $1,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of the same series and Tranche, of any authorized denominations, as requested by the Holder surrendering the same, and of like tenor upon surrender of the Security or Securities to be exchanged at the office of The Bank of New York Mellon Trust Company, National Association in New York, New York, or such other office or agency as may be designated by the Company from time to time.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the absolute owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

The Securities are not entitled to the benefit of any sinking fund.

As used herein, “Business Day” shall mean any day, other than Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York, New York. All other terms used in this Security which are defined in the Indenture shall have the meanings assigned to them in the Indenture.

As provided in the Indenture, no recourse shall be had for the payment of the principal of or premium, if any, or interest on any Securities, or any part thereof, or for any claim based thereon or otherwise in respect thereof, or of the indebtedness represented thereby, or upon any obligation, covenant or agreement under the Indenture, against, and no personal liability whatsoever shall attach to, or be incurred by, any incorporator, member, manager, stockholder, officer, director or employee, as such, past, present or future of the Company or of any predecessor or successor corporation (either directly or through the Company or a predecessor or successor corporation), whether by virtue of any constitutional provision, statute or rule of law, or by the enforcement of any assessment or penalty or otherwise; it being expressly agreed and understood that the Indenture and all the Securities are solely corporate obligations and that any such personal liability is hereby expressly waived and released as a condition of, and as part of the consideration for, the execution of the Indenture and the issuance of the Securities.

Unless the certificate of authentication hereon has been executed by the Trustee or an Authenticating Agent by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

[The remainder of this page is intentionally left blank.]

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC

Attest: By: _______________________________________________

Vincent A. Mercaldi Kristie L. Colvin

Assistant Secretary Senior Vice President and Chief Accounting Officer

(SEAL)

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture. Date of Authentication:, 2016

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee

By: ______________________________________________

SCHEDULE A

The initial aggregate principal amount of Securities evidenced by the Certificate to which this Schedule is attached is $300,000,000. The notations on the following table evidence decreases and increases in the aggregate principal amount of Securities evidenced by such Certificate.

			Aggregate Principal
			Amount of Securities
	Decrease in Aggregate	Increase in Aggregate	Remaining After	Notation by
Date of	Principal Amount of	Principal Amount of	Such Decrease or	Security
Adjustment	Securities	Securities	Increase	Registrar

EX-12

Exhibit 12

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES

	Six Months Ended June 30,
	2016			2015
	(in millions, except ratios)
Net income	$	152		$	208
Equity in earnings of unconsolidated affiliates, net of distributions	58			50
Income tax expense	96			115
Capitalized interest	(3		)	(5		)
	303			368
Fixed charges, as defined:
Interest	220			233
Capitalized interest	3			5
Interest component of rentals charged to operating expense	2			2
Total fixed charges	225			240
Earnings, as defined	$	528		$	608
Ratio of earnings to fixed charges	2.35			2.53

EX-31.1

Exhibit 31.1

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 5, 2016

/s/ Scott M. Prochazka

Scott M. Prochazka

President and Chief Executive Officer

EX-31.2

Exhibit 31.2

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 5, 2016

/s/ William D. Rogers

William D. Rogers

Executive Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

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, 2016 (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 5, 2016

EX-32.2

Exhibit 32.2

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, Inc. (the “Company”) on Form 10-Q for the quarter ended June 30, 2016 (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 5, 2016

XML

Document and Entity Supplemental Information Document - USD ($)	6 Months Ended
	Jun. 30, 2016	Jul. 29, 2016	Jun. 30, 2015
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, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		430,681,744
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 8,146,639,191

XML

Condensed Statements of Consolidated Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Statement [Abstract]
Revenues	$ 1,574	$ 1,532	$ 3,558	$ 3,965
Expenses:
Natural gas	496	529	1,348	1,883
Operation and maintenance	513	488	1,034	986
Depreciation and amortization	289	239	549	456
Taxes other than income taxes	94	90	195	198
Total	1,392	1,346	3,126	3,523
Operating Income	182	186	432	442
Other Income (Expense):
Gain on marketable securities	20	79	110	62
Loss on indexed debt securities	(130)	(91)	(186)	(67)
Interest and other finance charges	(86)	(89)	(173)	(178)
Interest on securitization bonds	(23)	(27)	(47)	(55)
Equity in earnings of unconsolidated affiliate, net	31	43	91	95
Other, net	14	13	21	24
Total	(174)	(72)	(184)	(119)
Income Before Income Taxes	8	114	248	323
Income tax expense	10	37	96	115
Net Income (Loss)	$ (2)	$ 77	$ 152	$ 208
Basic Earnings (Loss) Per Share	$ (0.01)	$ 0.18	$ 0.35	$ 0.48
Diluted Earnings (Loss) Per Share	(0.01)	0.18	0.35	0.48
Dividends Declared Per Share	$ 0.2575	$ 0.2475	$ 0.5150	$ 0.4950
Weighted Average Shares Outstanding, Basic	430,653,000	430,235,000	430,530,000	430,096,000
Weighted Average Shares Outstanding, Diluted	430,653,000	431,733,000	432,973,000	431,594,000

XML

Condensed Statements of Consolidated Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (2)	$ 77	$ 152	$ 208
Other comprehensive income (loss):
Adjustment related to pension and other postretirement plans (net of tax of $2, $-0-, $1 and $2)	(1)	2	0	4
Net deferred loss from cash flow hedges (net of tax of $1, $-0-, $1, $-0-)	(1)	0	(1)	0
Total	(2)	2	(1)	4
Comprehensive income (loss)	$ (4)	$ 79	$ 151	$ 212

XML

Comprehensive Income Parentheticals - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Tax benefit (expense) on adjustment related to pension and postretirement plans	$ 2	$ 0	$ 1	$ (2)
Tax benefit on net deferred loss from cash flow hedges	$ (1)	$ 0	$ (1)	$ 0

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents ($246 and $264 related to VIEs, respectively)	$ 271	$ 264
Investment in marketable securities	737	805
Accounts receivable ($92 and $64 related to VIEs, respectively), less bad debt reserve of $24 and $20, respectively	605	593
Accrued unbilled revenues	178	279
Natural gas inventory	96	168
Materials and supplies	187	179
Non-trading derivative assets	47	89
Taxes receivable	16	172
Prepaid expenses and other current assets ($37 and $35 related to VIEs, respectively)	135	140
Total current assets	2,272	2,689
Property, Plant and Equipment:
Property, plant and equipment	17,218	16,650
Less: accumulated depreciation and amortization	5,320	5,113
Property, plant and equipment, net	11,898	11,537
Other Assets:
Goodwill	861	840
Regulatory assets ($2,156 and $2,373 related to VIEs, respectively)	2,913	3,129
Notes receivable – unconsolidated affiliate	0	363
Non-trading derivative assets	22	36
Investment in unconsolidated affiliate	2,536	2,594
Preferred units – unconsolidated affiliate	363	0
Other	147	102
Total other assets	6,842	7,064
Total Assets	21,012	21,290
Current Liabilities:
Short-term borrowings	17	40
Current portion of VIE securitization bonds long-term debt	402	391
Indexed debt	111	145
Current portion of other long-term debt	250	328
Indexed debt securities derivative	490	442
Accounts payable	407	483
Taxes accrued	92	158
Interest accrued	119	117
Non-trading derivative liabilities	19	11
Other	334	343
Total current liabilities	2,241	2,458
Other Liabilities:
Deferred income taxes, net	5,121	5,047
Non-trading derivative liabilities	6	5
Benefit obligations	904	904
Regulatory liabilities	1,284	1,276
Other	279	273
Total other liabilities	7,594	7,505
Long-term Debt:
VIE securitization bonds	2,059	2,276
Other long-term debt	5,721	5,590
Total long-term debt	7,780	7,866
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Common stock (430,681,491 shares and 430,262,703 shares outstanding, respectively)	4	4
Additional paid-in capital	4,186	4,180
Accumulated deficit	(726)	(657)
Accumulated other comprehensive loss	(67)	(66)
Total shareholders’ equity	3,397	3,461
Total Liabilities and Shareholders’ Equity	$ 21,012	$ 21,290

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Balance Sheets Parentheticals - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Cash and cash equivalents	$ 271	$ 264
Bad debt reserve	24	20
Accounts receivable, net	605	593
Prepaid expenses and other current assets	135	140
Regulatory assets	$ 2,913	$ 3,129
Total common stock outstanding (in shares)	430,681,491	430,262,703
Variable Interest Entity, Primary Beneficiary [Member]
Cash and cash equivalents	$ 246	$ 264
Accounts receivable, net	92	64
Prepaid expenses and other current assets	37	35
Regulatory assets	$ 2,156	$ 2,373

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Condensed Statements of Consolidated Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Net income	$ 152	$ 208
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	549	456
Amortization of deferred financing costs	13	14
Deferred income taxes	69	4
Unrealized gain on marketable securities	(110)	(62)
Loss on indexed debt securities	186	67
Write-down of natural gas inventory	1	2
Equity in (earnings) losses of unconsolidated affiliate, net of distributions	(91)	50
Pension contributions	(5)	(25)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	147	367
Inventory	63	103
Taxes receivable	156	152
Accounts payable	(109)	(327)
Fuel cost recovery	(17)	86
Non-trading derivatives, net	22	2
Margin deposits, net	65	25
Interest and taxes accrued	(64)	(66)
Net regulatory assets and liabilities	(21)	78
Other current assets	4	23
Other current liabilities	21	(38)
Other liabilities	17	(3)
Other, net	10	6
Net cash provided by operating activities	1,058	1,122
Cash Flows from Investing Activities:
Capital expenditures	(682)	(712)
Acquisitions, net of cash acquired	(98)	0
Decrease in notes receivable – unconsolidated affiliate	363	0
Investment in preferred units – unconsolidated affiliate	(363)	0
Distributions from unconsolidated affiliate in excess of cumulative earnings	149	0
Decrease (increase) in restricted cash of Bond Companies	(2)	13
Proceeds from sale of marketable securities	178	32
Other, net	(12)	(4)
Net cash used in investing activities	(467)	(671)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(23)	(29)
Proceeds of commercial paper, net	278	137
Proceeds from long-term debt	300	0
Payments of long-term debt	(735)	(400)
Debt issuance costs	(7)	0
Payment of common stock dividends	(221)	(213)
Distribution to ZENS note holders	(178)	0
Other, net	2	1
Net cash used in financing activities	(584)	(504)
Net Increase (Decrease) in Cash and Cash Equivalents	7	(53)
Cash and Cash Equivalents at Beginning of Period	264	298
Cash and Cash Equivalents at End of Period	271	245
Cash Payments:
Interest, net of capitalized interest	200	209
Income tax refunds, net	(126)	(38)
Non-cash transactions:
Accounts payable related to capital expenditures	$ 79	$ 81

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Background and Basis of Presentation

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Background and Basis of Presentation [Text Block]

Background and Basis of Presentation

General. Included in this Form 10-Q are the Interim Condensed Financial Statements of CenterPoint Energy. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the 2015 Form 10-K.

Background. CenterPoint Energy, Inc. is a public utility holding company. CenterPoint Energy’s operating subsidiaries own and operate electric transmission and distribution facilities and natural gas distribution facilities, and both CenterPoint Energy and its operating subsidiaries own interests in Enable as described in Note 8. As of June 30, 2016, CenterPoint Energy’s indirect, wholly-owned subsidiaries included:

• Houston Electric, which engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston; and

• CERC Corp. (together with its subsidiaries), which owns and operates natural gas distribution systems. A wholly-owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and natural gas utilities. As of June 30, 2016, CERC Corp. also owned approximately 55.4% of the limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

As of June 30, 2016, CenterPoint Energy had VIEs consisting of Bond Companies, which it consolidates. 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 have no recourse to any assets or revenues of 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.

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.

CenterPoint Energy’s 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 CenterPoint Energy’s 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.

For a description of CenterPoint Energy’s reportable business segments, see Note 16.

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New Accounting Pronouncements

6 Months Ended

Jun. 30, 2016

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements [Text Block]

New Accounting Pronouncements

In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (ASU 2015-02). ASU 2015-02 changes the analysis that reporting organizations must perform to evaluate whether they should consolidate certain legal entities, such as limited partnerships. The changes include, among others, modification of the evaluation of whether limited partnerships and similar legal entities are VIEs or voting interest entities and elimination of the presumption that a general partner should consolidate a limited partnership. ASU 2015-02 does not amend the related party guidance for situations in which power is shared between two or more entities that hold interests in a VIE. CenterPoint Energy adopted ASU 2015-02 on January 1, 2016, which CenterPoint Energy determined did not have a material impact on its financial position, results of operations, cash flows and disclosures.

In April 2015, the FASB issued ASU No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Cost (ASU 2015-03). ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by ASU 2015-03. CenterPoint Energy adopted ASU 2015-03 retrospectively on January 1, 2016, which resulted in a reduction of other long-term assets, indexed debt and total long-term debt on its Condensed Consolidated Balance Sheets. CenterPoint Energy had debt issuance costs, excluding amounts related to credit facility arrangements, of $43 million and $44 million as of June 30, 2016 and December 31, 2015, respectively.

In May 2015, the FASB issued ASU No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent) (ASU 2015-07). ASU 2015-07 removes the requirement to categorize within the fair value hierarchy investments for which fair values are measured at NAV using the practical expedient. Entities will be required to disclose the fair value of investments measured using the NAV practical expedient so that financial statement users can reconcile amounts reported in the fair value hierarchy table to amounts reported on the balance sheet. CenterPoint Energy adopted ASU 2015-07 on January 1, 2016, which will have an impact on its employee benefit plan disclosures, beginning with its annual report on Form 10-K for the year ended December 31, 2016. This standard did not have an impact on CenterPoint Energy’s financial position, results of operations or cash flows.

In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments (ASU 2015-16). ASU 2015-16 eliminates the requirement for an acquirer in a business combination to account for measurement-period adjustments retrospectively. Instead, an acquirer would recognize a measurement-period adjustment during the period in which the amount of the adjustment is determined. CenterPoint Energy adopted ASU 2015-16 on January 1, 2016, which did not have an impact on its financial position, results of operations or cash flows.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities (ASU 2016-01). ASU 2016-01 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. ASU 2016-01 also changes certain disclosure requirements and other aspects related to recognition and measurement of financial assets and financial liabilities. ASU 2016-01 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). 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. ASU 2016-02 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018, with early adoption permitted. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

In March 2016, the FASB issued ASU No. 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novation on Existing Hedge Accounting Relationships (ASU 2016-05). ASU 2016-05 clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument in an existing hedging relationship would not, in and of itself, be considered a termination of the derivative instrument or a change in a critical term of the hedging relationship. This clarification applies to both cash flow and fair value hedging relationships. CenterPoint Energy adopted ASU 2016-05 prospectively in the first quarter of 2016, which did not have an impact on its financial position, results of operations, cash flows and disclosures.

In March, April, and May 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (ASU 2016-08), ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing (ASU 2016-10), and ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients (ASU 2016-12), respectively. ASU 2016-08, ASU 2016-10, and ASU 2016-12 clarify certain aspects of ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (ASU 2014-09), which supersedes most current revenue recognition guidance. CenterPoint Energy is currently evaluating the impact that ASU 2016-08, ASU 2016-10, ASU 2016-12, and ASU 2014-09 will have on its financial position, results of operations, cash flows and disclosures and expects to adopt these ASUs on January 1, 2018.

In March 2016, the FASB issued ASU No. 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (ASU 2016-09). ASU 2016-09 will change the accounting for certain aspects of share-based payments to employees, including the recognition of income tax effects of vested or settled awards in the income statement, instead of within additional paid-in capital. It will also increase the amount an employer can withhold to cover income taxes on awards and still qualify for the exception to liability classification for shares used to satisfy the employer’s statutory income tax withholding obligations. ASU 2016-09 will allow companies to elect between two different methods to account for forfeitures of share-based payments. ASU 2016-09 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (ASU 2016-13). ASU 2016-13 requires a new model called the CECL model to estimate credit losses for financial assets subject to credit losses and measured at amortized cost and certain off-balance sheet credit exposures. This includes loans, held-to-maturity debt securities, loan commitments, financial guarantees, and net investments in leases, as well as reinsurance and trade receivables. Upon initial recognition of the exposure, the CECL model requires an entity to estimate the credit losses expected over the life of an exposure based on historical information, current information and reasonable and supportable forecasts, including estimates of prepayments. The update also amends the other-than-temporary impairment model for debt securities classified as available-for-sale. ASU 2016-13 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted beginning after December 15, 2018. CenterPoint Energy is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures.

Management believes that other recently issued standards, which are not yet effective, will not have a material impact on CenterPoint Energy’s consolidated financial position, results of operations or cash flows upon adoption.

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Acquisition

6 Months Ended

Jun. 30, 2016

Business Combinations [Abstract]

Acquisition [Text Block]

Acquisition

On April 1, 2016,CES, an indirect, wholly-owned subsidiary of CenterPoint Energy, closed the previously announced agreement to acquire the retail energy services business and natural gas wholesale assets of Continuum for $98 million. The purchase price was allocated to identifiable assets acquired and liabilities assumed based on their estimated fair values on the acquisition date. As additional information becomes available, the preliminary purchase price allocation may be revised during the remainder of the measurement period (which will not exceed 12 months from the acquisition date). Any such revisions or changes are not expected to be material.

The following table summarizes the total preliminary purchase price allocation and the fair value amounts recognized for the assets acquired and liabilities assumed related to the acquisition:

	(in millions)
Total purchase price consideration	$	98
Receivables	$	75
Derivative assets	38
Property and equipment	1
Identifiable intangibles	36
Total assets acquired	150
Accounts payable	49
Derivative liabilities	24
Total liabilities assumed	73
Identifiable net assets acquired	77
Goodwill	21
Net assets acquired	$	98

The goodwill of $21 million resulting from the acquisition reflects the excess of the purchase price over the fair value of the net identifiable assets acquired. The goodwill recorded as part of the acquisition primarily reflects the value of the complementary operational and geographic footprints provided, along with the scale, geographic reach and expanded capabilities.

Identifiable intangible assets were recorded at estimated fair value as determined by management based on available information, which includes a preliminary valuation prepared by an independent third party. The significant assumptions used in arriving at the estimated identifiable intangible asset values included management’s estimates of future cash flows, the discount rate which is based on the weighted average cost of capital for comparable publicly traded guideline companies and projected customer attrition rates. The useful lives for the identifiable intangible assets were determined using methods that approximate the pattern of economic benefit provided by the utilization of the assets.

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

	Estimate Fair Value		Estimate Useful Life
	(in millions)		(in years)
Customer relationships	$	32	15
Covenants not to compete	4		4
Total identifiable intangibles	$	36

Amortization expense related to the above identifiable intangible assets was $1 million for the three and six months ended June 30, 2016 and is expected to be $2 million for 2016.

Revenues of $108 million and operating income of less than $1 million attributable to the acquisition are included in CenterPoint Energy’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2016.

As Continuum was a non-public company that did not prepare interim financial information, the historical financial information for the businesses and assets acquired was impracticable to obtain. As a result, pro forma results of the acquired businesses and assets are not presented.

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Employee Benefit Plans

6 Months Ended

Jun. 30, 2016

Compensation and Retirement Disclosure [Abstract]

Employee Benefit Plans [Text Block]

Employee Benefit Plans

CenterPoint Energy’s net periodic cost includes the following components relating to pension and postretirement benefits:

	Three Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	9		$	—		$	10		$	—
Interest cost	24			5			23			5
Expected return on plan assets	(25		)	(1		)	(30		)	(1		)
Amortization of prior service cost (credit)	2			(1		)	2			(1		)
Amortization of net loss	16			—			15			1
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	26		$	—		$	20		$	4
	Six Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	18		$	1		$	20		$	1
Interest cost	47			9			46			10
Expected return on plan assets	(50		)	(3		)	(60		)	(3		)
Amortization of prior service cost (credit)	4			(1		)	5			(1		)
Amortization of net loss	32			—			29			2
Settlement cost (2)	—			—			9			—
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	51		$	3		$	49		$	9

(1) Net periodic cost in these tables is before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes.  

(2) A one-time, non-cash settlement charge is required when lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of net periodic cost for that year.  Due to the amount of lump sum payment distributions from the non-qualified pension plan during the six months ended June 30, 2015, CenterPoint Energy recognized a non-cash settlement charge of $9 million.  This charge is an acceleration of costs that would otherwise be recognized in future periods. 

(3) A curtailment gain or loss is required when the expected future services of a significant number of current employees are reduced or eliminated for the accrual of benefits. In May 2016, Houston Electric entered into a renegotiated collective bargaining agreement with the IBEW Local Union 66 that provides that for Houston Electric union employees covered under the agreement who retire on or after January 1, 2017, retiree medical and prescription drug coverage will be provided exclusively through the NECA/IBEW Family Medical Care Plan in exchange for the payment of monthly premiums as determined under the agreement. As a result, the accrued postretirement benefits related to such future Houston Electric union retirees were eliminated. Houston Electric recognized a curtailment gain of $3 million as an accelerated recognition of the prior service credit that would otherwise be recognized in future periods.

CenterPoint Energy’s changes in accumulated comprehensive loss related to defined benefit and postretirement plans are as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	Pension and Postretirement Plans						Pension and Postretirement Plans
	(in millions)
Beginning Balance	$	(64	)	$	(83	)	$	(65	)	$	(85	)
Other comprehensive income (loss) before reclassifications (1)	(4		)	—			(4		)	—
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	1			2			3			6
Tax benefit (expense)	2			—			1			(2		)
Net current period other comprehensive income (loss)	(1		)	2			—			4
Ending Balance	$	(65	)	$	(81	)	$	(65	)	$	(81	)

(1) Total other comprehensive income (loss) related to the remeasurement of the postretirement plan.

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

CenterPoint Energy expects to contribute a total of approximately $8 million to its pension plans in 2016, of which approximately $2 million and $5 million were contributed during the three and six months ended June 30, 2016, respectively.

CenterPoint Energy expects to contribute a total of approximately $16 million to its postretirement benefit plan in 2016, of which approximately $4 million and $8 million were contributed during the three and six months ended June 30, 2016, respectively.

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Regulatory Accounting

6 Months Ended

Jun. 30, 2016

Regulatory Assets and Liabilities, Other Disclosures [Abstract]

Regulatory Accounting [Text Block]

Regulatory Accounting

As of June 30, 2016, Houston Electric has not recognized an allowed equity return of $363 million because such return will be recognized as it is recovered in rates. During the three months ended June 30, 2016 and 2015, Houston Electric recognized approximately $17 million and $12 million, respectively, of the allowed equity return not previously recognized. During the six months ended June 30, 2016 and 2015, Houston Electric recognized approximately $30 million and $21 million, respectively, of the allowed equity return not previously recognized.

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Derivative Instruments

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments [Text Block]

Derivative Instruments

CenterPoint Energy is exposed to various market risks. These risks arise from transactions entered into in the normal course of business.  CenterPoint Energy utilizes derivative instruments such as physical forward contracts, swaps and options to mitigate the impact of changes in commodity prices and weather on its operating results and cash flows. Such derivatives are recognized in CenterPoint Energy’s Condensed Consolidated Balance Sheets at their fair value unless CenterPoint Energy elects the normal purchase and sales exemption for qualified physical transactions. A derivative may be designated as a normal purchase or 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 CenterPoint Energy’s marketing, risk management services and hedging activities. The committee’s duties are to establish CenterPoint Energy’s commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions and ensure compliance with CenterPoint Energy’s risk management policies, procedures and limits established by CenterPoint Energy’s board of directors.

CenterPoint Energy’s 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 enters into certain derivative instruments to manage physical commodity price risk and does not engage in proprietary or speculative commodity trading.  These financial instruments do not qualify or are not designated as cash flow or fair value hedges.

Weather Hedges. CenterPoint Energy has 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 CenterPoint Energy’s other jurisdictions. As a result, fluctuations from normal weather may have a positive or negative effect on NGD’s results in Texas and on Houston Electric’s results in its service territory.

CenterPoint Energy has historically entered into heating-degree day swaps for certain NGD jurisdictions to mitigate the effect of fluctuations from normal weather on its results of operations and cash flows for the winter heating season, which contained a bilateral dollar cap of $16 million in 2014–2015. However, NGD did not enter into heating-degree day swaps for the 2015–2016 winter season as a result of NGD’s Minnesota division implementing a full decoupling pilot in July 2015. CenterPoint Energy also entered into weather hedges for the Houston Electric service territory, which contained a bilateral dollar cap of $8 million for the 2014–2015 winter season and a bilateral dollar cap of $7 million for the 2015–2016 winter season. The swaps are based on 10-year normal weather. During the three months ended June 30, 2016 and 2015, CenterPoint Energy recognized gains of $-0- and $1 million, respectively, related to these swaps. During the six months ended June 30, 2016 and 2015, CenterPoint Energy recognized gains of $3 million and losses of $9 million, respectively, related to these swaps. Weather hedge gains and losses are included in revenues in the Condensed Statements of Consolidated Income.

Hedging of Interest Expense for Future Debt Issuances. In April 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $150 million. These agreements were executed to hedge, in part, volatility in the 5-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows related to interest payments of Houston Electric’s $300 million issuance of fixed rate debt in May 2016. These forward interest rate agreements were designated as cash flow hedges. Accordingly, the ineffective portion of unrealized gains and losses associated with the agreements was recorded in income and was immaterial.

In June and July 2016, Houston Electric entered into forward interest rate agreements with several counterparties, having an aggregate notional amount of $300 million. These agreements were executed to hedge, in part, volatility in the 10-year U.S. treasury rate by reducing Houston Electric’s exposure to variability in cash flows relating to interest payments on a forecasted issuance of fixed rate debt in 2016.  These forward interest rate agreements were designated as cash flow hedges.  As of June 30, 2016, a $2 million current non-trading derivative liability was recorded on the Condensed Consolidated Balance Sheets related to these agreements. Accordingly, the effective portion of unrealized gains and losses associated with the agreements would be recorded as a component of accumulated other comprehensive income and the ineffective portion would be recorded in income.

(b) Derivative Fair Values and Income Statement Impacts

The following tables present information about CenterPoint Energy’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CenterPoint Energy’s Derivative Assets and Liabilities as of June 30, 2016 and December 31, 2015, while the last table provides a breakdown of the related income statement impacts for the three and six months ended June 30, 2016 and 2015.

Fair Value of Derivative Instruments
	June 30, 2016
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	49	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	28		6
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	28		45
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	—		6
Indexed debt securities derivative	Current Liabilities	—		490
Total		$	105	$	549

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,085 Bcf or a net 6 Bcf short position.  Of the net short position, basis swaps constitute a net 136 Bcf long position.

(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 $46 million asset, excluding a $2 million interest rate derivative liability, as shown on CenterPoint Energy’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, offset by collateral netting of less than $1 million.

(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
	June 30, 2016
	Gross AmountsRecognized (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	$	77		$	(30	)	$	47
Other Assets: Non-trading derivative assets	28			(6		)	22
Current Liabilities: Non-trading derivative liabilities	(47		)	30			(17		)
Other Liabilities: Non-trading derivative liabilities	(12		)	6			(6		)
Total	$	46		$	—		$	46

(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.

Fair Value of Derivative Instruments
	December 31, 2015
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	90	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	36		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	10		60
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	4		25
Indexed debt securities derivative	Current Liabilities	—		442
Total		$	140	$	529

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 767 Bcf or a net 112 Bcf long position.  Of the net long position, basis swaps constitute 133 Bcf.

(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 $109 million asset as shown on CenterPoint Energy’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, offset by collateral netting of $56 million.

(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
	December 31, 2015
	Gross AmountsRecognized (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	$	100		$	(11	)	$	89
Other Assets: Non-trading derivative assets	40			(4		)	36
Current Liabilities: Non-trading derivative liabilities	(62		)	51			(11		)
Other Liabilities: Non-trading derivative liabilities	(25		)	20			(5		)
Total	$	53		$	56		$	109

(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 retail sales derivative contracts and as natural gas expense for financial natural gas derivatives and non-retail related physical 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.

Income Statement Impact of Derivative Activity
		Three Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(50	)	$	7
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	59			1
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(130		)	(91		)
Total		$	(121	)	$	(83	)

Income Statement Impact of Derivative Activity
		Six Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(30	)	$	49
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	48			(42		)
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(186		)	(67		)
Total		$	(168	)	$	(60	)

(c) Credit Risk Contingent Features

CenterPoint Energy enters into financial derivative contracts containing material adverse change provisions.  These provisions could require CenterPoint Energy to post additional collateral if the S&P or Moody’s credit ratings of CenterPoint Energy, Inc. or its subsidiaries are downgraded.  The total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position as of both June 30, 2016 and December 31, 2015 was $3 million.  CenterPoint Energy posted no assets as collateral towards derivative instruments that contain credit risk contingent features as of either June 30, 2016 or December 31, 2015.  If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered as of both June 30, 2016 and December 31, 2015, $2 million of additional assets would be required to be posted as collateral.

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Fair Value Measurements

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements [Text Block]

Fair Value Measurements

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

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

Level 2: Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, 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 CenterPoint Energy’s 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 CenterPoint Energy’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. CenterPoint Energy develops these inputs based on the best information available, including CenterPoint Energy’s own data. A market approach is utilized to value CenterPoint Energy’s Level 3 assets or liabilities. As of June 30, 2016, CenterPoint Energy’s Level 3 assets and liabilities are comprised of physical forward contracts and options. Level 3 physical forward contracts are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.92 to $3.72 per one million British thermal units) as an unobservable input. Level 3 options are valued through Black-Scholes (including forward start) option models which include option volatilities (ranging from 0% to 85%) as an unobservable input.  CenterPoint Energy’s Level 3 derivative assets and liabilities consist of both long and short positions (forwards and options) and their fair value is sensitive to forward prices and volatilities. If forward prices decrease, CenterPoint Energy’s long forwards lose value whereas its short forwards gain in value.  If volatility decreases, CenterPoint Energy’s long options lose value whereas its short options gain in value.

CenterPoint Energy determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period.  For the six months ended June 30, 2016, there were no transfers between Level 1 and 2. CenterPoint Energy also recognizes 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 CenterPoint Energy’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015, and indicate the fair value hierarchy of the valuation techniques utilized by CenterPoint Energy to determine such fair value.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of June 30, 2016
	(in millions)
Assets
Corporate equities	$	739	$	—	$	—	$	—		$	739
Investments, including money market funds (2)	55		—		—		—			55
Natural gas derivatives (3)	7		77		21		(36		)	69
Total assets	$	801	$	77	$	21	$	(36	)	$	863
Liabilities
Indexed debt securities derivative	$	—	$	490	$	—	$	—		$	490
Interest rate derivatives	—		2		—		—			2
Natural gas derivatives (3)	5		49		5		(36		)	23
Total liabilities	$	5	$	541	$	5	$	(36	)	$	515

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of less than $1 million 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.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of December 31, 2015
	(in millions)
Assets
Corporate equities	$	807	$	—	$	—	$	—		$	807
Investments, including money market funds (2)	53		—		—		—			53
Natural gas derivatives (3)	4		115		21		(15		)	125
Total assets	$	864	$	115	$	21	$	(15	)	$	985
Liabilities
Indexed debt securities derivative	$	—	$	442	$	—	$	—		$	442
Natural gas derivatives (3)	13		65		9		(71		)	16
Total liabilities	$	13	$	507	$	9	$	(71	)	$	458

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $56 million 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 has utilized Level 3 inputs to determine fair value:

	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative assets and liabilities, net
	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(in millions)
Beginning balance	$	15		$	13		$	12		$	17
Purchases	12			—			12			—
Total gains	—			—			4			—
Total settlements	(11		)	(3		)	(16		)	(6		)
Transfers into Level 3	—			—			5			—
Transfers out of Level 3	—			—			(1		)	(1		)
Ending balance (1)	$	16		$	10		$	16		$	10
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	3		$	—		$	11		$	2

(1) CenterPoint Energy did not have significant Level 3 sales during either of the three or six months ended June 30, 2016 or 2015.

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 the market price. These assets and liabilities, which are not measured at fair value in the Condensed Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 or Level 2 in the fair value hierarchy.

	June 30, 2016				December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial assets:
Notes receivable – unconsolidated affiliate	$	—	$	—	$	363	$	356
Financial liabilities:
Long-term debt	$	8,432	$	9,207	$	8,585	$	9,067

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Unconsolidated Affiliates

6 Months Ended

Jun. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Unconsolidated Affiliates [Text Block]

Unconsolidated Affiliate

On May 1, 2013 (the Formation Date) CERC Corp., OGE and ArcLight closed on the formation of Enable. CenterPoint Energy has the ability to significantly influence the operating and financial policies of Enable and, accordingly, accounts for its investment in Enable’s common and subordinated units using the equity method of accounting.

CenterPoint Energy’s maximum exposure to loss related to Enable, a VIE in which CenterPoint Energy is not the primary beneficiary, is limited to its equity investment and preferred unit investment as presented in the Condensed Consolidated Balance Sheets as of June 30, 2016, the guarantees discussed in Note 14, and outstanding current accounts receivable from Enable. On February 18, 2016, CenterPoint Energy purchased in a Private Placement an aggregate of 14,520,000 Series A Preferred Units from Enable for a total purchase price of $363 million, which is accounted for as a cost method investment. During the three months ended June 30, 2016, CenterPoint Energy received a cash distribution of approximately $4 million for the partial period from February 18, 2016 through March 31, 2016 with respect to its investment in Series A Preferred Units. In connection with the Private Placement, Enable redeemed $363 million of notes owed to a wholly-owned subsidiary of CERC Corp., which bore interest at an annual rate of 2.10% to 2.45%. CenterPoint Energy recorded interest income of $-0- and $2 million during the three months ended June 30, 2016 and 2015, respectively, and $1 million and $4 million during the six months ended June 30, 2016 and 2015, respectively, and had interest receivable from Enable of $-0- and $4 million as of June 30, 2016 and December 31, 2015, respectively, on its notes receivable.

Effective on the Formation Date, CenterPoint Energy and Enable entered into the Transition Agreements. Under the Services Agreement, CenterPoint Energy agreed to provide certain support services to Enable such as accounting, legal, risk management and treasury functions for an initial term, which ended on April 30, 2016.  CenterPoint Energy is providing certain services to Enable on a year-to-year basis. Enable may terminate (i) the entire Services Agreement with at least 90 days’ notice prior to the end of any extension term, or (ii) either any service provided under the Services Agreement, or the entire Services Agreement, at any time upon approval by its board of directors and with at least 180 days’ notice.

CenterPoint Energy billed Enable for reimbursement of transition services of $2 million during both the three months ended June 30, 2016 and 2015, and $5 million and $7 million during the six months ended June 30, 2016 and 2015, respectively, under the Transition Agreements. Actual transition services costs are recorded net of reimbursements received from Enable. CenterPoint Energy had accounts receivable from Enable of $1 million and $3 million as of June 30, 2016 and December 31, 2015, respectively, for amounts billed for transition services.

CenterPoint Energy incurred natural gas expenses, including transportation and storage costs, of $24 million and $26 million during the three months ended June 30, 2016 and 2015, respectively, and $57 million and $65 million during the six months ended June 30, 2016 and 2015, respectively, for transactions with Enable. CenterPoint Energy had accounts payable to Enable of $8 million and $11 million as of June 30, 2016 and December 31, 2015, respectively, from such transactions.

As of June 30, 2016, CenterPoint Energy held an approximate 55.4% limited partner interest in Enable, consisting of 94,151,707 common units and 139,704,916 subordinated units. As of June 30, 2016, CenterPoint Energy and OGE each own a 50% management interest in the general partner of Enable and a 40% and 60% interest, respectively, in the incentive distribution rights held by the general partner. Additionally, as of June 30, 2016, CenterPoint Energy held 14,520,000 Series A Preferred Units in Enable.

CenterPoint Energy evaluates its equity method investments and cost method investments for impairment when factors indicate that a decrease in value of its investment has occurred and the carrying amount of its investment may not be recoverable. An impairment loss, based on the excess of the carrying value over the best estimate of fair value of the investment, is recognized in earnings when an impairment is deemed to be other than temporary. Considerable judgment is used in determining if an impairment loss is other than temporary and the amount of any impairment. As of June 30, 2016, the carrying value of CenterPoint Energy’s equity method investment in Enable was $10.85 per unit, which includes limited partner common and subordinated units, a general partner interest and incentive distribution rights. On June 30, 2016, Enable’s common unit price closed at $13.51.

As there were no identified events or changes in circumstances that may have a significant adverse effect on the fair value of CenterPoint Energy’s cost method investment in Enable’s Series A Preferred Units as of June 30, 2016, and the investment’s fair value is not readily determinable, an estimate of the fair value of the cost method investment was not performed.

Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Operating revenues	$	529	$	590	$	1,038	$	1,206
Cost of sales, excluding depreciation and amortization	254		277		449		569
Operating income	57		93		160		197
Net income attributable to Enable	35		77		121		168
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	19	$	42	$	67	$	93
Basis difference amortization	12		1		24		2
CenterPoint Energy’s equity in earnings, net	$	31	$	43	$	91	$	95

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

	June 30, 2016			December 31, 2015
	(in millions)
Current assets	$	349		$	381
Non-current assets	10,851			10,857
Current liabilities	301			615
Non-current liabilities	3,150			3,092
Non-controlling interest	11			12
Preferred equity	362			—
Enable partners’ equity	7,376			7,519
Reconciliation of Equity Method Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ capital	$	4,084		$	4,163
CenterPoint Energy’s basis difference	(1,548		)	(1,569		)
CenterPoint Energy’s equity method investment in Enable	$	2,536		$	2,594

Distributions Received from Unconsolidated Affiliate:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	75	$	73	$	149	$	145

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Goodwill

6 Months Ended

Jun. 30, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill [Text Block]

Goodwill

Goodwill by reportable business segment as of December 31, 2015 and changes in the carrying amount of goodwill as of June 30, 2016 are as follows:

	December 31, 2015			Continuum Acquisition (1)		June 30, 2016
	(in millions)
Natural Gas Distribution	$	746		$	—	$	746
Energy Services	83		(2)	21		104
Other Operations	11			—		11
Total	$	840		$	21	$	861

(1) See Note 3.

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

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Capital Stock

6 Months Ended

Jun. 30, 2016

Class of Stock Disclosures [Abstract]

Capital Stock [Text Block]

Capital Stock

CenterPoint Energy, Inc. has 1,020,000,000 authorized shares of capital stock, comprised of 1,000,000,000 shares of $0.01 par value common stock and 20,000,000 shares of $0.01 par value cumulative preferred stock. As of June 30, 2016, 430,681,657 shares of CenterPoint Energy, Inc. common stock were issued and 430,681,491 shares were outstanding. As of December 31, 2015, 430,262,869 shares of CenterPoint Energy, Inc. common stock were issued and 430,262,703 shares were outstanding. Outstanding common shares exclude 166 treasury shares as of both June 30, 2016 and December 31, 2015.

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Indexed Debt Securities (ZENS) and Securities Related to ZENS

6 Months Ended

Jun. 30, 2016

Indexed Debt Securities [Text Block]

Indexed Debt Securities (ZENS) and Securities Related to ZENS

(a) Investment in Securities Related to ZENS

In 1995, CenterPoint Energy sold a cable television subsidiary to TW and received TW securities as partial consideration. A subsidiary of CenterPoint Energy now holds 7.1 million shares of TW Common, 0.9 million shares of Time Common and 0.9 million shares of Charter Common, 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 TW Securities are recorded in CenterPoint Energy’s Statements of Consolidated Income.

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1 billion of which $828 million remain outstanding at June 30, 2016. Each ZENS note 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 note are adjusted for certain corporate events. Prior to the merger described below, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.125505 share of TWC Common and 0.0625 share of Time Common.

On May 26, 2015, Charter announced that it had entered into a definitive merger agreement with TWC. On September 21, 2015, Charter shareholders approved the announced transaction with TWC. Pursuant to the merger agreement, upon closing of the merger, TWC Common would be exchanged for cash and Charter Common and as a result, reference shares for the ZENS would consist of Charter Common, TW Common and Time Common. The merger closed on May 18, 2016. CenterPoint Energy received $100 and 0.4891 shares of Charter Common for each share of TWC Common held, resulting in cash proceeds of $178 million and 872,531 shares of Charter Common. In accordance with the terms of the ZENS, CenterPoint Energy remitted $178 million to ZENS note holders in June 2016, which reduced contingent principal.  As a result, CenterPoint Energy recorded the following:

	(in millions)
Cash payment to ZENS note holders	$	178
Indexed debt – reduction	(40		)
Indexed debt securities derivative – reduction	(21		)
Loss on indexed debt securities	$	117

As of June 30, 2016, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.0625 share of Time Common and 0.061382 share of Charter Common, and the contingent principal balance was $519 million.

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Short-Term Borrowings and Long-term Debt

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

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

Short-term Borrowings and Long-term Debt

(a) Short-term Borrowings

Inventory Financing. NGD has asset management agreements associated with its utility distribution service in Arkansas, north Louisiana and Oklahoma that extend through 2019. 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 a financing and had an associated principal obligation of $17 million and $40 million as of June 30, 2016 and December 31, 2015, respectively.

(b) Long-term Debt

Debt Repayments. In May 2016, CERC retired approximately $325 million aggregate principal amount of its 6.15% senior notes at their maturity. The retirement of senior notes was financed by the issuance of commercial paper.

Houston Electric General Mortgage Bonds. In May 2016, Houston Electric issued $300 million aggregate principal amount of 1.85% general mortgage bonds due 2021. The proceeds from the issuance of the bonds were used to repay short-term debt and for general corporate purposes.

Credit Facilities. On March 4, 2016, CenterPoint Energy announced that it had refinanced its existing $2.1 billion revolving credit facilities, which would have expired in 2019, with new revolving credit facilities totaling an aggregate $2.5 billion. The credit agreements evidencing the new revolving credit facilities provide for five-year senior unsecured revolving credit facilities in amounts of $1.6 billion for CenterPoint Energy, $300 million for Houston Electric and $600 million for CERC Corp.

As of June 30, 2016 and December 31, 2015, CenterPoint Energy, Houston Electric and CERC Corp. had the following revolving credit facilities and utilization of such facilities:

	June 30, 2016									December 31, 2015
	Size of Facility		Loans		Letters of Credit		Commercial Paper			Size of Facility		Loans			Letters of Credit		Commercial Paper
	(in millions)
CenterPoint Energy	$	1,600	$	—	$	6	$	1,037	(1)	$	1,200	$	—		$	6	$	716	(1)
Houston Electric	300		—		4		—			300		200		(2)	4		—
CERC Corp.	600		—		3		176		(3)	600		—			2		219		(3)
Total	$	2,500	$	—	$	13	$	1,213		$	2,100	$	200		$	12	$	935

(1) Weighted average interest rate was 0.82% and 0.79% as of June 30, 2016 and December 31, 2015, respectively.

(2) Weighted average interest rate was 1.637% as of December 31, 2015.

(3) Weighted average interest rate was 0.68% and 0.81% as of June 30, 2016 and December 31, 2015, respectively.

CenterPoint Energy’s $1.6 billion revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CenterPoint Energy’s current credit ratings. The revolving credit facility contains a financial covenant which limits CenterPoint Energy’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of CenterPoint Energy’s consolidated capitalization. As of June 30, 2016, CenterPoint Energy’s debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 55.5%. 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 twelve-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.

Houston Electric’s $300 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.125% based on Houston Electric’s current credit ratings. The revolving credit facility contains a financial covenant which limits Houston Electric’s consolidated debt (with certain exceptions, including but not limited to Securitization Bonds) to an amount not to exceed 65% of Houston Electric’s consolidated capitalization. As of June 30, 2016, Houston Electric’s debt (excluding Securitization Bonds) to capital ratio, as defined in its credit facility agreement, was 52.7%. 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 Houston Electric certifies to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-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 Houston Electric delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of Houston Electric’s certification or (iii) the revocation of such certification.

CERC Corp.’s $600 million revolving credit facility, which is scheduled to terminate on March 3, 2021, can be drawn at LIBOR plus 1.25% based on CERC Corp.’s current credit ratings. The revolving credit facility contains a financial covenant which limits CERC’s consolidated debt to an amount not to exceed 65% of CERC’s consolidated capitalization. As of June 30, 2016, CERC’s debt to capital ratio, as defined in its credit facility agreement, was 30.7%.

CenterPoint Energy, Houston Electric and CERC Corp. were in compliance with all financial covenants as of June 30, 2016.

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Income Taxes

6 Months Ended

Jun. 30, 2016

Income Tax Disclosure [Abstract]

Income Taxes [Text Block]

Income Taxes

The effective tax rate reported for the three months ended June 30, 2016 was 125% compared to 32% for the same period in 2015. The higher effective tax rate for the three months ended June 30, 2016 is due to a Louisiana state tax law change resulting in an increase to CenterPoint Energy’s deferred tax liability, the effect of which was compounded by lower earnings.

The effective tax rate reported for the six months ended June 30, 2016 was 39% compared to 36% for the same period in 2015. The higher effective tax rate for the six months ended June 30, 2016 is due to a Louisiana state tax law change discussed above.

CenterPoint Energy reported no uncertain tax liability as of June 30, 2016 and expects no significant change to the uncertain tax liability over the next twelve months. CenterPoint Energy’s consolidated federal income tax returns have been audited and settled through 2014. CenterPoint Energy is under examination by the IRS for 2015 and 2016.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies [Text Block]

Commitments and Contingencies

(a) Natural Gas Supply Commitments

Natural gas supply commitments include natural gas contracts related to CenterPoint Energy’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 Condensed Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015 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, 2016, minimum payment obligations for natural gas supply commitments are approximately $190 million for the remaining six months in 2016, $473 million in 2017, $456 million in 2018, $270 million in 2019, $132 million in 2020 and $127 million after 2020.

(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, nor does it affect the terms of existing guarantee arrangements for certain GenOn gas transportation contracts discussed below.

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. That ruling is subject to appeal. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims.  CenterPoint Energy does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows.

Environmental Matters

Manufactured Gas Plant Sites. 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, 2016, 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 Environmental Protection Agency 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 does 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 CenterPoint Energy or its predecessors contain or have contained asbestos insulation and other asbestos-containing materials. CenterPoint Energy and its subsidiaries 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 CenterPoint Energy anticipates that additional claims may be asserted in the future.  Although their ultimate outcome cannot be predicted at this time, CenterPoint Energy does not expect these matters, either individually or in the aggregate, to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

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

Other Proceedings

CenterPoint Energy is 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, CenterPoint Energy is also a defendant 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. CenterPoint Energy regularly analyzes current information and, as necessary, provides accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. CenterPoint Energy does not expect the disposition of these matters to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

(c) Guarantees

Prior to the distribution of CenterPoint Energy’s ownership in RRI to its shareholders, CERC had guaranteed certain contractual obligations of what became RRI’s trading subsidiary.  When the companies separated, RRI agreed to secure CERC against obligations under the guarantees RRI had been unable to extinguish by the time of separation.  Pursuant to such agreement, as amended in December 2007, RRI (now GenOn) agreed to provide to CERC cash or letters of credit as security against CERC’s obligations under its remaining guarantees for demand charges under certain gas transportation agreements if and to the extent changes in market conditions expose CERC to a risk of loss on those guarantees based on an annual calculation, with any required collateral to be posted each December.  The undiscounted maximum potential payout of the demand charges under these transportation contracts, which will be in effect until 2018, was approximately $20 million as of June 30, 2016.  Based on market conditions in the fourth quarter of 2015 at the time the most recent annual calculation was made under the agreement, GenOn was not obligated to post any security. If GenOn should fail to perform the contractual obligations, CERC could have to honor its guarantee and, in such event, any collateral then provided as security may be insufficient to satisfy CERC’s obligations.

In 2010, CenterPoint Energy provided a guarantee (the CenterPoint Midstream Guarantee) with respect to the performance of certain obligations of Enable under a long-term gas gathering and treating agreement with an indirect, wholly-owned subsidiary of Royal Dutch Shell plc. Under the terms of the omnibus agreement entered into in connection with the closing of the formation of Enable, Enable and CenterPoint Energy have agreed to use commercially reasonable efforts and cooperate with each other to terminate the CenterPoint Midstream Guarantee and to release CenterPoint Energy from such guarantee. As of June 30, 2016, CenterPoint Energy had guaranteed Enable’s obligations up to an aggregate amount of $50 million under the CenterPoint Midstream Guarantee.

CERC Corp. had also provided a guarantee of collection of $1.1 billion of Enable’s senior notes due 2019 and 2024. This guarantee was subordinated to all senior debt of CERC Corp. and was automatically released on May 1, 2016.

The fair value of these guarantees is not material.

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Earnings Per Share

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

Earnings Per Share

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016				2015		2016		2015
	(in millions, except share and per share amounts)
Net income (loss)	$	(2	)		$	77	$	152	$	208
Basic weighted average shares outstanding	430,653,000				430,235,000		430,530,000		430,096,000
Plus: Incremental shares from assumed conversions:
Restricted stock	—			(1)	1,498,000		2,443,000		1,498,000
Diluted weighted average shares	430,653,000				431,733,000		432,973,000		431,594,000
Basic earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48
Diluted earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48

(1) 2,443,000 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 months ended June 30, 2016, as their inclusion would be anti-dilutive.

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Reportable Business Segments

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Reportable Business Segments [Text Block]

Reportable Business Segments

CenterPoint Energy’s determination of reportable business segments considers the strategic operating units under which CenterPoint Energy manages sales, allocates resources and assesses performance of various products and services to wholesale or retail customers in differing regulatory environments. CenterPoint Energy uses operating income as the measure of profit or loss for its business segments.

CenterPoint Energy’s reportable business segments include the following: Electric Transmission & Distribution, Natural Gas Distribution, Energy Services, Midstream Investments and Other Operations. The electric transmission and distribution function is reported in the Electric Transmission & Distribution business segment. 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 represents CenterPoint Energy’s non-rate regulated gas sales and services operations. Midstream Investments consists of CenterPoint Energy’s investment in Enable. Other Operations consists primarily of other corporate operations which support all of CenterPoint Energy’s business operations.

Financial data for business segments is as follows:

	For the Three Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	763	(1)	$	—		$	158
Natural Gas Distribution	414			7			20
Energy Services	393			4			—
Midstream Investments (2)	—			—			—
Other Operations	4			—			4
Eliminations	—			(11		)	—
Consolidated	$	1,574		$	—		$	182

	For the Three Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	705	(1)	$	—		$	158
Natural Gas Distribution	420			7			19
Energy Services	404			4			9
Midstream Investments (2)	—			—			—
Other Operations	3			—			—
Eliminations	—			(11		)	—
Consolidated	$	1,532		$	—		$	186

	For the Six Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of June 30, 2016
	(in millions)
Electric Transmission & Distribution	$	1,423	(1)	$	—		$	241	$	10,065
Natural Gas Distribution	1,302			14			180		5,585
Energy Services	825			11			6		973
Midstream Investments (2)	—			—			—		2,536
Other Operations	8			—			5		2,771			(3)
Eliminations	—			(25		)	—		(918		)
Consolidated	$	3,558		$	—		$	432	$	21,012

	For the Six Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of December 31, 2015
	(in millions)
Electric Transmission & Distribution	$	1,317	(1)	$	—		$	254	$	10,028
Natural Gas Distribution	1,605			15			165		5,657
Energy Services	1,036			22			22		857
Midstream Investments (2)	—			—			—		2,594
Other Operations	7			—			1		2,879			(3)
Eliminations	—			(37		)	—		(725		)
Consolidated	$	3,965		$	—		$	442	$	21,290

(1) Electric Transmission & Distribution revenues from major customers are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Affiliates of NRG	$	159	$	172	$	304	$	356
Affiliates of Energy Future Holdings Corp.	$	50	$	51	$	95	$	103

(2) Midstream Investments’ equity earnings are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	31	$	43	$	91	$	95

Midstream Investments’ total assets are as follows:

	June 30, 2016		December 31, 2015
	(in millions)
Enable	$	2,536	$	2,594

(3) Included in total assets of Other Operations as of June 30, 2016 and December 31, 2015 are pension and other postemployment-related regulatory assets of $791 million and $814 million, respectively.

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Subsequent Events

6 Months Ended

Jun. 30, 2016

Subsequent Events [Abstract]

Subsequent Events [Text Block]

Subsequent Events

On July 28, 2016, CenterPoint Energy’s board of directors declared a regular quarterly cash dividend of $0.2575 per share of common stock payable on September 9, 2016, to shareholders of record as of the close of business on August 16, 2016.

On August 2, 2016, Enable declared a quarterly cash distribution of $0.318 per unit on all of its outstanding common and subordinated units for the quarter ended June 30, 2016. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million from Enable in the third quarter of 2016 to be made with respect to CERC Corp.’s investment in common and subordinated units in Enable for the second quarter of 2016.

On August 2, 2016, Enable declared a quarterly cash distribution of $0.625 per Series A Preferred Unit for the quarter ended June 30, 2016. Accordingly, CenterPoint Energy expects to receive a cash distribution of approximately $9 million from Enable in the third quarter of 2016 to be made with respect to CenterPoint Energy’s investment in Series A Preferred Units of Enable for the second quarter of 2016.

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Acquisition (Tables)

6 Months Ended

Jun. 30, 2016

Business Combinations [Abstract]

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

The following table summarizes the total preliminary purchase price allocation and the fair value amounts recognized for the assets acquired and liabilities assumed related to the acquisition:

	(in millions)
Total purchase price consideration	$	98
Receivables	$	75
Derivative assets	38
Property and equipment	1
Identifiable intangibles	36
Total assets acquired	150
Accounts payable	49
Derivative liabilities	24
Total liabilities assumed	73
Identifiable net assets acquired	77
Goodwill	21
Net assets acquired	$	98

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

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

	Estimate Fair Value		Estimate Useful Life
	(in millions)		(in years)
Customer relationships	$	32	15
Covenants not to compete	4		4
Total identifiable intangibles	$	36

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2016

Compensation and Retirement Disclosure [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

CenterPoint Energy’s net periodic cost includes the following components relating to pension and postretirement benefits:

	Three Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	9		$	—		$	10		$	—
Interest cost	24			5			23			5
Expected return on plan assets	(25		)	(1		)	(30		)	(1		)
Amortization of prior service cost (credit)	2			(1		)	2			(1		)
Amortization of net loss	16			—			15			1
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	26		$	—		$	20		$	4
	Six Months Ended June 30,
	2016						2015
	Pension Benefits (1)			Postretirement Benefits (1)			Pension Benefits (1)			Postretirement Benefits (1)
	(in millions)
Service cost	$	18		$	1		$	20		$	1
Interest cost	47			9			46			10
Expected return on plan assets	(50		)	(3		)	(60		)	(3		)
Amortization of prior service cost (credit)	4			(1		)	5			(1		)
Amortization of net loss	32			—			29			2
Settlement cost (2)	—			—			9			—
Curtailment gain (3)	—			(3		)	—			—
Net periodic cost	$	51		$	3		$	49		$	9

(1) Net periodic cost in these tables is before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes.  

(2) A one-time, non-cash settlement charge is required when lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of net periodic cost for that year.  Due to the amount of lump sum payment distributions from the non-qualified pension plan during the six months ended June 30, 2015, CenterPoint Energy recognized a non-cash settlement charge of $9 million.  This charge is an acceleration of costs that would otherwise be recognized in future periods. 

(3) A curtailment gain or loss is required when the expected future services of a significant number of current employees are reduced or eliminated for the accrual of benefits. In May 2016, Houston Electric entered into a renegotiated collective bargaining agreement with the IBEW Local Union 66 that provides that for Houston Electric union employees covered under the agreement who retire on or after January 1, 2017, retiree medical and prescription drug coverage will be provided exclusively through the NECA/IBEW Family Medical Care Plan in exchange for the payment of monthly premiums as determined under the agreement. As a result, the accrued postretirement benefits related to such future Houston Electric union retirees were eliminated. Houston Electric recognized a curtailment gain of $3 million as an accelerated recognition of the prior service credit that would otherwise be recognized in future periods.

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

CenterPoint Energy’s changes in accumulated comprehensive loss related to defined benefit and postretirement plans are as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	Pension and Postretirement Plans						Pension and Postretirement Plans
	(in millions)
Beginning Balance	$	(64	)	$	(83	)	$	(65	)	$	(85	)
Other comprehensive income (loss) before reclassifications (1)	(4		)	—			(4		)	—
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	1			2			3			6
Tax benefit (expense)	2			—			1			(2		)
Net current period other comprehensive income (loss)	(1		)	2			—			4
Ending Balance	$	(65	)	$	(81	)	$	(65	)	$	(81	)

(1) Total other comprehensive income (loss) related to the remeasurement of the postretirement plan.

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

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Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Instruments [Table Text Block]

The following tables present information about CenterPoint Energy’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CenterPoint Energy’s Derivative Assets and Liabilities as of June 30, 2016 and December 31, 2015, while the last table provides a breakdown of the related income statement impacts for the three and six months ended June 30, 2016 and 2015.

Fair Value of Derivative Instruments
	June 30, 2016
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	49	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	28		6
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	28		45
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	—		6
Indexed debt securities derivative	Current Liabilities	—		490
Total		$	105	$	549

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,085 Bcf or a net 6 Bcf short position.  Of the net short position, basis swaps constitute a net 136 Bcf long position.

(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 $46 million asset, excluding a $2 million interest rate derivative liability, as shown on CenterPoint Energy’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, offset by collateral netting of less than $1 million.

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

Fair Value of Derivative Instruments
	December 31, 2015
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2) (3)	Current Assets: Non-trading derivative assets	$	90	$	2
Natural gas derivatives (1) (2) (3)	Other Assets: Non-trading derivative assets	36		—
Natural gas derivatives (1) (2) (3)	Current Liabilities: Non-trading derivative liabilities	10		60
Natural gas derivatives (1) (2) (3)	Other Liabilities: Non-trading derivative liabilities	4		25
Indexed debt securities derivative	Current Liabilities	—		442
Total		$	140	$	529

(1) The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 767 Bcf or a net 112 Bcf long position.  Of the net long position, basis swaps constitute 133 Bcf.

(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 $109 million asset as shown on CenterPoint Energy’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, offset by collateral netting of $56 million.

(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
	June 30, 2016
	Gross AmountsRecognized (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	$	77		$	(30	)	$	47
Other Assets: Non-trading derivative assets	28			(6		)	22
Current Liabilities: Non-trading derivative liabilities	(47		)	30			(17		)
Other Liabilities: Non-trading derivative liabilities	(12		)	6			(6		)
Total	$	46		$	—		$	46

(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.

Offsetting of Natural Gas Derivative Assets and Liabilities
	December 31, 2015
	Gross AmountsRecognized (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	$	100		$	(11	)	$	89
Other Assets: Non-trading derivative assets	40			(4		)	36
Current Liabilities: Non-trading derivative liabilities	(62		)	51			(11		)
Other Liabilities: Non-trading derivative liabilities	(25		)	20			(5		)
Total	$	53		$	56		$	109

(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]

Realized and unrealized gains and losses on natural gas derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for retail sales derivative contracts and as natural gas expense for financial natural gas derivatives and non-retail related physical 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.

Income Statement Impact of Derivative Activity
		Three Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(50	)	$	7
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	59			1
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(130		)	(91		)
Total		$	(121	)	$	(83	)

Income Statement Impact of Derivative Activity
		Six Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2016			2015
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenues	$	(30	)	$	49
Natural gas derivatives	Gains (Losses) in Expenses: Natural Gas	48			(42		)
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(186		)	(67		)
Total		$	(168	)	$	(60	)

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

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

The following tables present information about CenterPoint Energy’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015, and indicate the fair value hierarchy of the valuation techniques utilized by CenterPoint Energy to determine such fair value.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of June 30, 2016
	(in millions)
Assets
Corporate equities	$	739	$	—	$	—	$	—		$	739
Investments, including money market funds (2)	55		—		—		—			55
Natural gas derivatives (3)	7		77		21		(36		)	69
Total assets	$	801	$	77	$	21	$	(36	)	$	863
Liabilities
Indexed debt securities derivative	$	—	$	490	$	—	$	—		$	490
Interest rate derivatives	—		2		—		—			2
Natural gas derivatives (3)	5		49		5		(36		)	23
Total liabilities	$	5	$	541	$	5	$	(36	)	$	515

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of less than $1 million 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.

	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments (1)			Balance as of December 31, 2015
	(in millions)
Assets
Corporate equities	$	807	$	—	$	—	$	—		$	807
Investments, including money market funds (2)	53		—		—		—			53
Natural gas derivatives (3)	4		115		21		(15		)	125
Total assets	$	864	$	115	$	21	$	(15	)	$	985
Liabilities
Indexed debt securities derivative	$	—	$	442	$	—	$	—		$	442
Natural gas derivatives (3)	13		65		9		(71		)	16
Total liabilities	$	13	$	507	$	9	$	(71	)	$	458

(1) Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $56 million 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 has utilized Level 3 inputs to determine fair value:

	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative assets and liabilities, net
	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(in millions)
Beginning balance	$	15		$	13		$	12		$	17
Purchases	12			—			12			—
Total gains	—			—			4			—
Total settlements	(11		)	(3		)	(16		)	(6		)
Transfers into Level 3	—			—			5			—
Transfers out of Level 3	—			—			(1		)	(1		)
Ending balance (1)	$	16		$	10		$	16		$	10
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	3		$	—		$	11		$	2

(1) CenterPoint Energy did not have significant Level 3 sales during either of the three or six months ended June 30, 2016 or 2015.

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

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 the market price. These assets and liabilities, which are not measured at fair value in the Condensed Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 or Level 2 in the fair value hierarchy.

	June 30, 2016				December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial assets:
Notes receivable – unconsolidated affiliate	$	—	$	—	$	363	$	356
Financial liabilities:
Long-term debt	$	8,432	$	9,207	$	8,585	$	9,067

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Unconsolidated Affiliates (Tables)

6 Months Ended

Jun. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Summarized unaudited consolidated income information for Enable is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Operating revenues	$	529	$	590	$	1,038	$	1,206
Cost of sales, excluding depreciation and amortization	254		277		449		569
Operating income	57		93		160		197
Net income attributable to Enable	35		77		121		168
Reconciliation of Equity in Earnings, net:
CenterPoint Energy’s interest	$	19	$	42	$	67	$	93
Basis difference amortization	12		1		24		2
CenterPoint Energy’s equity in earnings, net	$	31	$	43	$	91	$	95

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

	June 30, 2016			December 31, 2015
	(in millions)
Current assets	$	349		$	381
Non-current assets	10,851			10,857
Current liabilities	301			615
Non-current liabilities	3,150			3,092
Non-controlling interest	11			12
Preferred equity	362			—
Enable partners’ equity	7,376			7,519
Reconciliation of Equity Method Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ capital	$	4,084		$	4,163
CenterPoint Energy’s basis difference	(1,548		)	(1,569		)
CenterPoint Energy’s equity method investment in Enable	$	2,536		$	2,594

Distributions Received from Unconsolidated Affiliate:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	75	$	73	$	149	$	145

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Goodwill (Tables)

6 Months Ended

Jun. 30, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill [Table Text Block]

Goodwill by reportable business segment as of December 31, 2015 and changes in the carrying amount of goodwill as of June 30, 2016 are as follows:

	December 31, 2015			Continuum Acquisition (1)		June 30, 2016
	(in millions)
Natural Gas Distribution	$	746		$	—	$	746
Energy Services	83		(2)	21		104
Other Operations	11			—		11
Total	$	840		$	21	$	861

(1) See Note 3.

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

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

6 Months Ended

Jun. 30, 2016

Investments, Debt and Equity Securities [Abstract]

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

On May 26, 2015, Charter announced that it had entered into a definitive merger agreement with TWC. On September 21, 2015, Charter shareholders approved the announced transaction with TWC. Pursuant to the merger agreement, upon closing of the merger, TWC Common would be exchanged for cash and Charter Common and as a result, reference shares for the ZENS would consist of Charter Common, TW Common and Time Common. The merger closed on May 18, 2016. CenterPoint Energy received $100 and 0.4891 shares of Charter Common for each share of TWC Common held, resulting in cash proceeds of $178 million and 872,531 shares of Charter Common. In accordance with the terms of the ZENS, CenterPoint Energy remitted $178 million to ZENS note holders in June 2016, which reduced contingent principal.  As a result, CenterPoint Energy recorded the following:

	(in millions)
Cash payment to ZENS note holders	$	178
Indexed debt – reduction	(40		)
Indexed debt securities derivative – reduction	(21		)
Loss on indexed debt securities	$	117

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

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

Credit Facilities. On March 4, 2016, CenterPoint Energy announced that it had refinanced its existing $2.1 billion revolving credit facilities, which would have expired in 2019, with new revolving credit facilities totaling an aggregate $2.5 billion. The credit agreements evidencing the new revolving credit facilities provide for five-year senior unsecured revolving credit facilities in amounts of $1.6 billion for CenterPoint Energy, $300 million for Houston Electric and $600 million for CERC Corp.

As of June 30, 2016 and December 31, 2015, CenterPoint Energy, Houston Electric and CERC Corp. had the following revolving credit facilities and utilization of such facilities:

	June 30, 2016									December 31, 2015
	Size of Facility		Loans		Letters of Credit		Commercial Paper			Size of Facility		Loans			Letters of Credit		Commercial Paper
	(in millions)
CenterPoint Energy	$	1,600	$	—	$	6	$	1,037	(1)	$	1,200	$	—		$	6	$	716	(1)
Houston Electric	300		—		4		—			300		200		(2)	4		—
CERC Corp.	600		—		3		176		(3)	600		—			2		219		(3)
Total	$	2,500	$	—	$	13	$	1,213		$	2,100	$	200		$	12	$	935

(1) Weighted average interest rate was 0.82% and 0.79% as of June 30, 2016 and December 31, 2015, respectively.

(2) Weighted average interest rate was 1.637% as of December 31, 2015.

(3) Weighted average interest rate was 0.68% and 0.81% as of June 30, 2016 and December 31, 2015, respectively.

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

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

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016				2015		2016		2015
	(in millions, except share and per share amounts)
Net income (loss)	$	(2	)		$	77	$	152	$	208
Basic weighted average shares outstanding	430,653,000				430,235,000		430,530,000		430,096,000
Plus: Incremental shares from assumed conversions:
Restricted stock	—			(1)	1,498,000		2,443,000		1,498,000
Diluted weighted average shares	430,653,000				431,733,000		432,973,000		431,594,000
Basic earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48
Diluted earnings (loss) per share
Net income (loss)	$	(0.01	)		$	0.18	$	0.35	$	0.48

(1) 2,443,000 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 months ended June 30, 2016, as their inclusion would be anti-dilutive.

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Reportable Business Segments (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

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

Financial data for business segments is as follows:

	For the Three Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	763	(1)	$	—		$	158
Natural Gas Distribution	414			7			20
Energy Services	393			4			—
Midstream Investments (2)	—			—			—
Other Operations	4			—			4
Eliminations	—			(11		)	—
Consolidated	$	1,574		$	—		$	182

	For the Three Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)
Electric Transmission & Distribution	$	705	(1)	$	—		$	158
Natural Gas Distribution	420			7			19
Energy Services	404			4			9
Midstream Investments (2)	—			—			—
Other Operations	3			—			—
Eliminations	—			(11		)	—
Consolidated	$	1,532		$	—		$	186

	For the Six Months Ended June 30, 2016
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of June 30, 2016
	(in millions)
Electric Transmission & Distribution	$	1,423	(1)	$	—		$	241	$	10,065
Natural Gas Distribution	1,302			14			180		5,585
Energy Services	825			11			6		973
Midstream Investments (2)	—			—			—		2,536
Other Operations	8			—			5		2,771			(3)
Eliminations	—			(25		)	—		(918		)
Consolidated	$	3,558		$	—		$	432	$	21,012

	For the Six Months Ended June 30, 2015
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of December 31, 2015
	(in millions)
Electric Transmission & Distribution	$	1,317	(1)	$	—		$	254	$	10,028
Natural Gas Distribution	1,605			15			165		5,657
Energy Services	1,036			22			22		857
Midstream Investments (2)	—			—			—		2,594
Other Operations	7			—			1		2,879			(3)
Eliminations	—			(37		)	—		(725		)
Consolidated	$	3,965		$	—		$	442	$	21,290

(1) Electric Transmission & Distribution revenues from major customers are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Affiliates of NRG	$	159	$	172	$	304	$	356
Affiliates of Energy Future Holdings Corp.	$	50	$	51	$	95	$	103

(2) Midstream Investments’ equity earnings are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	31	$	43	$	91	$	95

Midstream Investments’ total assets are as follows:

	June 30, 2016		December 31, 2015
	(in millions)
Enable	$	2,536	$	2,594

(3) Included in total assets of Other Operations as of June 30, 2016 and December 31, 2015 are pension and other postemployment-related regulatory assets of $791 million and $814 million, respectively.

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

Electric Transmission & Distribution revenues from major customers are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Affiliates of NRG	$	159	$	172	$	304	$	356
Affiliates of Energy Future Holdings Corp.	$	50	$	51	$	95	$	103

Midstream Investments [Table Text Block]

Midstream Investments’ equity earnings are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(in millions)
Enable	$	31	$	43	$	91	$	95

Midstream Investments’ total assets are as follows:

	June 30, 2016		December 31, 2015
	(in millions)
Enable	$	2,536	$	2,594

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Background and Basis of Presentation (Details)	Jun. 30, 2016
Enable Midstream Partners [Member]
Equity Method Investment, Ownership Percentage	55.40%

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New Accounting Pronouncements (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Unamortized Debt Issuance Expense	$ 43	$ 44

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Acquisition (Details) - USD ($) $ in Millions		3 Months Ended	6 Months Ended
	Apr. 01, 2016	Jun. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Business Acquisition [Line Items]
Total Acquisition Cost			$ 98	$ 0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Total Acquisition Cost			98	$ 0
Goodwill		$ 861	861		$ 840
Continuum Energy Services [Member]
Business Acquisition [Line Items]
Total Acquisition Cost	$ 98
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Total Acquisition Cost	98
Receivables	75
Derivative assets	38
Property and equipment	1
Identifiable intangibles	36
Total assets acquired	150
Accounts payable	49
Derivative liabilities	24
Total liabilities assumed	73
Identifiable net assets acquired	77
Goodwill	21
Net assets acquired	98
Amortization of Intangible Assets		1	1
Expected Amortization Of Intangible Assets in 2016			2
Revenue of Acquiree since Acquisition Date		$ 108	$ 108
Operating Income of Acquiree since Acquisition Date		less than $1 million	less than $1 million
Continuum Energy Services [Member] | Customer Relationships [Member]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Finite-lived Identifiable Intangible Assets Acquired, Fair Value	$ 32
Finite-lived Identifiable Intangible Assets Acquired, Estimated Useful Life	15 years
Continuum Energy Services [Member] | Noncompete Agreements [Member]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Finite-lived Identifiable Intangible Assets Acquired, Fair Value	$ 4
Finite-lived Identifiable Intangible Assets Acquired, Estimated Useful Life	4 years

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Employee Benefit Plans (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Defined Benefit Plan, Change in Accumulated Comprehensive Loss [Roll Forward]
Beginning Balance		$ (64)	$ (83)	$ (65)	$ (85)
Other comprehensive income (loss) before reclassifications (1)	[1]	(4)	0	(4)	0
Amounts reclassified from accumulated other comprehensive loss:
Actuarial losses (2)	[2]	1	2	3	6
Tax benefit (expense)		2	0	1	(2)
Net current period other comprehensive income (loss)		(1)	2	0	4
Ending Balance		(65)	(81)	(65)	(81)
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	[3]	9	10	18	20
Interest cost	[3]	24	23	47	46
Expected return on plan assets	[3]	(25)	(30)	(50)	(60)
Amortization of prior service cost (credit)	[3]	2	2	4	5
Amortization of net loss	[3]	16	15	32	29
Settlement cost (2)	[3],[4]			0	9
Curtailment gain (3)	[3],[5]	0	0	0	0
Net periodic cost	[3]	26	20	51	49
Total contributions expected in current year				8
Total contributions to the plans during the period		2		5
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	[3]	0	0	1	1
Interest cost	[3]	5	5	9	10
Expected return on plan assets	[3]	(1)	(1)	(3)	(3)
Amortization of prior service cost (credit)	[3]	(1)	(1)	(1)	(1)
Amortization of net loss	[3]	0	1	0	2
Settlement cost (2)	[3],[4]			0	0
Curtailment gain (3)	[3],[5]	(3)	0	(3)	0
Net periodic cost	[3]	0	$ 4	3	$ 9
Total contributions expected in current year				16
Total contributions to the plans during the period		$ 4		$ 8

[1] Total other comprehensive income (loss) related to the remeasurement of the postretirement plan.

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

[3] Net periodic cost in these tables is before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes.

[4] A one-time, non-cash settlement charge is required when lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of net periodic cost for that year. Due to the amount of lump sum payment distributions from the non-qualified pension plan during the six months ended June 30, 2015, CenterPoint Energy recognized a non-cash settlement charge of $9 million. This charge is an acceleration of costs that would otherwise be recognized in future periods.

[5] A curtailment gain or loss is required when the expected future services of a significant number of current employees are reduced or eliminated for the accrual of benefits. In May 2016, Houston Electric entered into a renegotiated collective bargaining agreement with the IBEW Local Union 66 that provides that for Houston Electric union employees covered under the agreement who retire on or after January 1, 2017, retiree medical and prescription drug coverage will be provided exclusively through the NECA/IBEW Family Medical Care Plan in exchange for the payment of monthly premiums as determined under the agreement. As a result, the accrued postretirement benefits related to such future Houston Electric union retirees were eliminated. Houston Electric recognized a curtailment gain of $3 million as an accelerated recognition of the prior service credit that would otherwise be recognized in future periods.

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Regulatory Accounting (Details) - CenterPoint Houston [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Amount of allowed equity return on the true-up balance that has not been recognized	$ 363		$ 363
Amount of allowed equity return on the true-up balance that was recognized in the period	$ 17	$ 12	$ 30	$ 21

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Derivative Instruments Derivatives and hedging (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	May 13, 2016
Derivatives, Fair Value [Line Items]
Weather Hedges Term			10 years
Gains (Losses) in Revenue [Member] | Weather Hedge Swaps [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ 1	$ 3	$ (9)
2014 To 2015 [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather Hedge, Bilateral Cap Amount			8
2014 To 2015 [Member] | Natural Gas Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather Hedge, Bilateral Cap Amount			16
2015 To 2016 [Member] | Electric Transmission and Distribution [Member]
Derivatives, Fair Value [Line Items]
Weather Hedge, Bilateral Cap Amount			7
CenterPoint Houston [Member] | Bonds General Mortgage Due 2021 [Member]
Derivatives, Fair Value [Line Items]
Debt Instrument, Face Amount					$ 300
April [Member] | Treasury Lock [Member]
Derivatives, Fair Value [Line Items]
Aggregate Notional Amount	150		150
June and July [Member] | Treasury Lock [Member]
Derivatives, Fair Value [Line Items]
Aggregate Notional Amount	300		300
Current Liabilities [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities, at Fair Value	$ 2		$ 2

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Derivative Instruments Derivative Fair Values (Details)		3 Months Ended			6 Months Ended			12 Months Ended
		Jun. 30, 2016 USD ($)		Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) Bcf		Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($) Bcf
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value		$ 105,000,000			$ 105,000,000			$ 140,000,000
Indexed debt securities derivative		549,000,000			549,000,000			529,000,000
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		(121,000,000)		$ (83,000,000)	(168,000,000)		$ (60,000,000)
Derivative, Fair Value, Net [Abstract]
Total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position		3,000,000			3,000,000			3,000,000
The aggregate fair value of assets already posted as collateral		0			0			0
Credit Risk Contingent Features assets		2,000,000			$ 2,000,000			$ 2,000,000
Natural gas derivatives [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf					1,085			767
Derivative, Fair Value, Net [Abstract]
Gross Amounts Recognized	[1]	46,000,000			$ 46,000,000			$ 53,000,000
Gross amounts offset, Net		0			0			56,000,000
Net Amount Presented in the Consolidated Balance Sheets	[2]	46,000,000			46,000,000			109,000,000
Collateral Netting		1,000,000			1,000,000			56,000,000
Natural gas derivatives [Member] | Gains (Losses) in Revenue [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		(50,000,000)		7,000,000	(30,000,000)		49,000,000
Natural gas derivatives [Member] | Gains (Losses) in Expense: Natural Gas [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		59,000,000		1,000,000	48,000,000		(42,000,000)
Natural gas derivatives [Member] | Current Assets [Member]
Derivative, Fair Value, Net [Abstract]
Gross Amounts Recognized	[1]	77,000,000			77,000,000			100,000,000
Gross amounts offset		(30,000,000)			(30,000,000)			(11,000,000)
Derivative Asset	[2]	47,000,000			47,000,000			89,000,000
Natural gas derivatives [Member] | Other Assets [Member]
Derivative, Fair Value, Net [Abstract]
Gross Amounts Recognized	[1]	28,000,000			28,000,000			40,000,000
Gross amounts offset		(6,000,000)			(6,000,000)			(4,000,000)
Derivative Asset	[2]	22,000,000			22,000,000			36,000,000
Natural gas derivatives [Member] | Current Liabilities [Member]
Derivative, Fair Value, Net [Abstract]
Gross Amounts Recognized	[1]	(47,000,000)			(47,000,000)			(62,000,000)
Gross amounts offset		30,000,000			30,000,000			51,000,000
Derivative Liability	[2]	(17,000,000)			(17,000,000)			(11,000,000)
Natural gas derivatives [Member] | Other Liabilities [Member]
Derivative, Fair Value, Net [Abstract]
Gross Amounts Recognized	[1]	(12,000,000)			(12,000,000)			(25,000,000)
Gross amounts offset		6,000,000			6,000,000			20,000,000
Derivative Liability	[2]	(6,000,000)			(6,000,000)			(5,000,000)
Interest Rate Contract [Member] | Current Liabilities [Member]
Derivative, Fair Value, Net [Abstract]
Interest Rate Derivative Liabilities, at Fair Value		2,000,000			2,000,000
Indexed debt securities derivative | Gains (losses) in Other Income (Expense) [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		(130,000,000)		$ (91,000,000)	(186,000,000)		$ (67,000,000)
Not Designated as Hedging Instrument [Member] | Natural gas derivatives [Member] | Current Assets [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value	[3]	49,000,000	[4],[5]		49,000,000	[4],[5]		90,000,000	[6],[7]
Indexed debt securities derivative	[3]	2,000,000	[4],[5]		2,000,000	[4],[5]		2,000,000	[6],[7]
Not Designated as Hedging Instrument [Member] | Natural gas derivatives [Member] | Other Assets [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value	[3]	28,000,000	[4],[5]		28,000,000	[4],[5]		36,000,000	[6],[7]
Indexed debt securities derivative	[3]	6,000,000	[4],[5]		6,000,000	[4],[5]		0	[6],[7]
Not Designated as Hedging Instrument [Member] | Natural gas derivatives [Member] | Current Liabilities [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value	[3]	28,000,000	[4],[5]		28,000,000	[4],[5]		10,000,000	[6],[7]
Indexed debt securities derivative	[3]	45,000,000	[4],[5]		45,000,000	[4],[5]		60,000,000	[6],[7]
Not Designated as Hedging Instrument [Member] | Natural gas derivatives [Member] | Other Liabilities [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value	[3]	0	[4],[5]		0	[4],[5]		4,000,000	[6],[7]
Indexed debt securities derivative	[3]	6,000,000	[4],[5]		6,000,000	[4],[5]		25,000,000	[6],[7]
Not Designated as Hedging Instrument [Member] | Indexed debt securities derivative | Current Liabilities [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Asset, Fair Value		0			0			0
Indexed debt securities derivative		$ 490,000,000			$ 490,000,000			$ 442,000,000
Short [Member] | Natural gas derivatives [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf					6
Long [Member] | Natural gas derivatives [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf								112
Swap [Member] | Long [Member] | Natural gas derivatives [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf					136			133

[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.

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

[4] 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 $46 million asset, excluding a $2 million interest rate derivative liability, as shown on CenterPoint Energy’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, offset by collateral netting of less than $1 million.

[5] The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 1,085 Bcf or a net 6 Bcf short position. Of the net short position, basis swaps constitute a net 136 Bcf long position.

[6] Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities was a $109 million asset as shown on CenterPoint Energy’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, offset by collateral netting of $56 million.

[7] The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 767 Bcf or a net 112 Bcf long position. Of the net long position, basis swaps constitute 133 Bcf.

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Fair Value Measurements (Details)		3 Months Ended			6 Months Ended
		Jun. 30, 2016 USD ($)		Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($)		Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount		$ 0			$ 0
Fair Value, Assets, Level 2 to Level 1 Transfers, Amount		0			0
Fair Value, Liabilities, Level 1 to Level 2 Transfers, Amount		0			0
Fair Value, Liabilities, Level 2 to Level 1 Transfers, Amount		0			0
Assets
Natural gas derivatives, netting adjustment		(36,000,000)	[1]		(36,000,000)	[1]		$ (15,000,000)	[2]
Total assets		863,000,000			863,000,000			985,000,000
Liabilities
Natural gas derivatives, netting adjustment		(36,000,000)	[1]		(36,000,000)	[1]		(71,000,000)	[2]
Total liabilities		515,000,000			515,000,000			458,000,000
Cash collateral posted with counterparties		1,000,000			1,000,000			56,000,000
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		15,000,000		$ 13,000,000	12,000,000		$ 17,000,000
Purchases		12,000,000		0	12,000,000		0
Total gains		0		0	4,000,000		0
Total settlements		(11,000,000)		(3,000,000)	(16,000,000)		(6,000,000)
Transfers into Level 3		0		0	5,000,000		0
Transfers out of Level 3		0		0	(1,000,000)		(1,000,000)
Ending balance (1)	[3]	16,000,000		10,000,000	16,000,000		10,000,000
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date		3,000,000		$ 0	11,000,000		$ 2,000,000
Fair Value, Inputs, Level 1 [Member]
Assets
Total assets		801,000,000			801,000,000			864,000,000
Liabilities
Total liabilities		5,000,000			5,000,000			13,000,000
Fair Value, Inputs, Level 2 [Member]
Assets
Total assets		77,000,000			77,000,000			115,000,000
Liabilities
Total liabilities		541,000,000			541,000,000			507,000,000
Fair Value, Inputs, Level 3 [Member]
Assets
Total assets		21,000,000			21,000,000			21,000,000
Liabilities
Total liabilities		5,000,000			$ 5,000,000			9,000,000
Forward Contracts [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair Value Inputs, Price Per MMBtu					1.92
Forward Contracts [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair Value Inputs, Price Per MMBtu					3.72
Options Held [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair Value Assumptions, Expected Volatility Rate					0.00%
Options Held [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Fair Value Assumptions, Expected Volatility Rate					85.00%
Estimate of Fair Value Measurement [Member]
Estimated Fair Value of Financial Instruments
Notes receivable – unconsolidated affiliate		0			$ 0			356,000,000
Long-term debt		9,207,000,000			9,207,000,000			9,067,000,000
Reported Value Measurement [Member]
Estimated Fair Value of Financial Instruments
Notes receivable – unconsolidated affiliate		0			0			363,000,000
Long-term debt		8,432,000,000			8,432,000,000			8,585,000,000
Fair Value, Measurements, Recurring [Member]
Assets
Corporate equities		739,000,000			739,000,000			807,000,000
Investments, including money market funds (2)	[4]	55,000,000			55,000,000			53,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Corporate equities		739,000,000			739,000,000			807,000,000
Investments, including money market funds (2)	[4]	55,000,000			55,000,000			53,000,000
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
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
Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member]
Assets
Natural gas derivatives, netting adjustment	[5]	(36,000,000)	[1]		(36,000,000)	[1]		(15,000,000)	[2]
Derivative Asset	[5]	69,000,000			69,000,000			125,000,000
Liabilities
Natural gas derivatives, netting adjustment	[5]	(36,000,000)	[1]		(36,000,000)	[1]		(71,000,000)	[2]
Derivative Liabilities	[5]	23,000,000			23,000,000			16,000,000
Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Natural gas derivatives (3)	[5]	7,000,000			7,000,000			4,000,000
Liabilities
Derivative Liability, Fair Value	[5]	5,000,000			5,000,000			13,000,000
Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Natural gas derivatives (3)	[5]	77,000,000			77,000,000			115,000,000
Liabilities
Derivative Liability, Fair Value	[5]	49,000,000			49,000,000			65,000,000
Fair Value, Measurements, Recurring [Member] | Natural gas derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Natural gas derivatives (3)	[5]	21,000,000			21,000,000			21,000,000
Liabilities
Derivative Liability, Fair Value	[5]	5,000,000			5,000,000			9,000,000
Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member]
Liabilities
Natural gas derivatives, netting adjustment		0	[1]		0	[1]		0	[2]
Derivative Liabilities		490,000,000			490,000,000			442,000,000
Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member] | Fair Value, Inputs, Level 1 [Member]
Liabilities
Derivative Liability, Fair Value		0			0			0
Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member] | Fair Value, Inputs, Level 2 [Member]
Liabilities
Derivative Liability, Fair Value		490,000,000			490,000,000			442,000,000
Fair Value, Measurements, Recurring [Member] | IDS Derivative [Member] | Fair Value, Inputs, Level 3 [Member]
Liabilities
Derivative Liability, Fair Value		0			0			$ 0
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member]
Liabilities
Natural gas derivatives, netting adjustment	[1]	0			0
Interest Rate Derivative Liabilities, at Fair Value		2,000,000			2,000,000
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Liabilities
Interest Rate Derivative Liabilities, at Fair Value		0			0
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Liabilities
Interest Rate Derivative Liabilities, at Fair Value		2,000,000			2,000,000
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Liabilities
Interest Rate Derivative Liabilities, at Fair Value		$ 0			$ 0

[1] Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of less than $1 million posted with the same counterparties.

[2] Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $56 million posted with the same counterparties.

[3] CenterPoint Energy did not have significant Level 3 sales during either of the three or six months ended June 30, 2016 or 2015.

[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 Affiliates Description (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended		6 Months Ended
	Feb. 18, 2016	Mar. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Preferred units – unconsolidated affiliate			$ 363		$ 363		$ 0
Service Agreement Notice For Termination At Term End, Number of Days					90 days
Service Agreement Notice For Termination At Will, Number Of Days					180 days
Enable Midstream Partners [Member]
Equity Method Investment, Ownership Percentage			55.40%		55.40%
Equity Method Investment, Carrying Value Per Unit			$ 10.85		$ 10.85
Enable Midstream Partners [Member]
Share Price			$ 13.51		$ 13.51
Series A Preferred Stock [Member] | Enable Midstream Partners [Member]
Purchase of Preferred Units, Price Per Unit	14,520,000
Preferred units – unconsolidated affiliate			$ 363		$ 363
Purchase of Preferred Units, Number of Units Purchased			14,520,000		14,520,000
Redeemable Preferred Stock [Member] | Enable Midstream Partners [Member]
Proceeds from Cost Method Investment, Dividends or Distributions		$ 4
Common Stock [Member] | Enable Midstream Partners [Member]
Equity Method Investment, Ownership, Shares			94,151,707		94,151,707
Subordinated Units [Member] | Enable Midstream Partners [Member]
Equity Method Investment, Ownership, Shares			139,704,916		139,704,916
Enable Midstream Partners [Member]
Extinguishment of Debt, Amount	$ 363
Interest Income (Expense), Net			$ 0	$ 2	$ 1	$ 4
Interest Receivable			0		0		4
Transitional Service [Member] | Enable Midstream Partners [Member]
Reimbursement for Transitional Services			2	2	5	7
Transitional Service cost receivable			1		1		3
Natural Gas Expenses [Member] | Enable Midstream Partners [Member]
Cost of natural gas purchases, affiliates			24	$ 26	57	$ 65
Due to Affiliate			$ 8		$ 8		$ 11
Enable Midstream Partners [Member] | CERC Corp [Member]
Management Rights Ownership Percentage					50.00%
Incentive Distribution Right					40.00%
Enable Midstream Partners [Member] | OGE [Member]
Management Rights Ownership Percentage					50.00%
Incentive Distribution Right					60.00%
Indebtedness to CERC Corp. [Member] | Enable Midstream Partners [Member]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum					2.10%
Debt Instrument, Interest Rate, Stated Percentage					2.45%

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Unconsolidated Affiliates Financial Data (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]
CenterPoint Energy’s equity method investment in Enable	$ 2,536,000,000		$ 2,536,000,000		$ 2,594,000,000
Enable Midstream Partners [Member]
Equity Method Investment, Summarized Financial Information, Gross Profit (Loss) [Abstract]
Operating revenues	529,000,000	$ 590,000,000	1,038,000,000	$ 1,206,000,000
Cost of sales, excluding depreciation and amortization	254,000,000	277,000,000	449,000,000	569,000,000
Operating income	57,000,000	93,000,000	160,000,000	197,000,000
Net income attributable to Enable	35,000,000	77,000,000	121,000,000	168,000,000
CenterPoint Energy’s interest	19,000,000	42,000,000	67,000,000	93,000,000
Basis difference amortization	12,000,000	1,000,000	24,000,000	2,000,000
CenterPoint Energy’s equity in earnings, net	31,000,000	43,000,000	91,000,000	95,000,000
Equity Method Investment, Summarized Financial Information, Assets [Abstract]
Current assets	349,000,000		349,000,000		381,000,000
Non-current assets	10,851,000,000		10,851,000,000		10,857,000,000
Current liabilities	301,000,000		301,000,000		615,000,000
Non-current liabilities	3,150,000,000		3,150,000,000		3,092,000,000
Non-controlling interest	11,000,000		11,000,000		12,000,000
Preferred equity	362,000,000		362,000,000		0
Enable partners’ equity	7,376,000,000		7,376,000,000		7,519,000,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity [Abstract]
CenterPoint Energy’s ownership interest in Enable partners’ capital	4,084,000,000		4,084,000,000		4,163,000,000
CenterPoint Energy’s basis difference	(1,548,000,000)		(1,548,000,000)		(1,569,000,000)
CenterPoint Energy’s equity method investment in Enable	2,536,000,000		2,536,000,000		$ 2,594,000,000
Proceeds from Equity Method Investment, Dividends or Distributions	$ 75,000,000	$ 73,000,000	$ 149,000,000	$ 145,000,000

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Goodwill (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2016	Dec. 31, 2015
Goodwill [Line Items]
Goodwill, Beginning Balance		$ 840
Goodwill, Acquired During Period	[1]	21
Goodwill, Ending Balance		861
Natural Gas Distribution [Member]
Goodwill [Line Items]
Goodwill, Beginning Balance		746
Goodwill, Acquired During Period	[1]	0
Goodwill, Ending Balance		746
Energy Services [Member]
Goodwill [Line Items]
Goodwill, Beginning Balance	[2]	83
Goodwill, Acquired During Period	[1]	21
Goodwill, Ending Balance		104
Goodwill, Impaired, Accumulated Impairment Loss			$ 252
Corporate and Other [Member]
Goodwill [Line Items]
Goodwill, Beginning Balance		11
Goodwill, Acquired During Period	[1]	0
Goodwill, Ending Balance		$ 11

[1] See Note 3.

[2] Amount presented is net of accumulated goodwill impairment charge of $252 million.

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Capital Stock (Details) - $ / shares	Jun. 30, 2016	Dec. 31, 2015
Capital stock shares authorized (in shares)	1,020,000,000
Common stock shares authorized (in shares)	1,000,000,000
Common stock shares par value (in dollars per share)	$ 0.01
Cumulative preferred stock shares authorized (in shares)	20,000,000
Cumulative preferred stock par value (in dollars per share)	$ 0.01
Total common stock issued (in shares)	430,681,657	430,262,869
Total common stock outstanding (in shares)	430,681,491	430,262,703
Treasury stock (in shares)	166	166

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Indexed Debt Securities (ZENS) and Securities Related to ZENS (Details) $ / shares in Units, $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2016 USD ($) shares	Jun. 30, 2016 USD ($) shares	Jun. 30, 2015 USD ($)	May 18, 2016 $ / shares shares	May 17, 2016
Cash payment to ZENS note holders	$ 178	$ 178	$ 0
Indexed debt – reduction	(40)
Indexed debt securities derivative – reduction	(21)
Loss on indexed debt securities	117
Subordinated Debt ZENS [Member]
Debt Instrument, Face Amount	1,000	1,000
Long-term Debt, Gross	828	$ 828
Subordinated Note Cash Exchangeable Percentage Of Fair Value		95.00%
Debt Instrument Contingent Principal Amount Outstanding	$ 519	$ 519
TW Common [Member]
Investment Owned, Balance, Shares | shares	7,100,000	7,100,000
TW Common [Member] | Subordinated Debt ZENS [Member]
Number Of Shares Referenced In Exchangeable Subordinated Note	0.5	0.5			0.5
TWC Common [Member]
Cash received per share of TWC Common held | $ / shares				$ 100
Fractional Shares Exchanged for each TWC Common Shares Held | shares				0.4891
TWC Common [Member] | Subordinated Debt ZENS [Member]
Number Of Shares Referenced In Exchangeable Subordinated Note					0.125505
Time Common [Member]
Investment Owned, Balance, Shares | shares	900,000	900,000
Time Common [Member] | Subordinated Debt ZENS [Member]
Number Of Shares Referenced In Exchangeable Subordinated Note	0.0625	0.0625			0.0625
Charter Common [Member]
Investment Owned, Balance, Shares | shares	900,000	900,000
Cash Proceeds Received	$ 178
Total Charter Common Shares Received in Exchange for TWC Common Shares Held | shares				872,531
Charter Common [Member] | Subordinated Debt ZENS [Member]
Number Of Shares Referenced In Exchangeable Subordinated Note	0.061382	0.061382

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Short-Term Borrowings and Long-term Debt (Details) $ in Millions		6 Months Ended
		Jun. 30, 2016 USD ($)	May 13, 2016 USD ($)	May 01, 2016 USD ($)	Dec. 31, 2015 USD ($)
Short-term Debt [Line Items]
Total short term borrowings		$ 17			$ 40
Line of Credit Facility [Abstract]
Total credit facility amount		2,500			2,100
CenterPoint Houston [Member]
Line of Credit Facility [Abstract]
Total credit facility amount		$ 300			300
Debt Instrument, Term		5 years
CERC Corp [Member]
Line of Credit Facility [Abstract]
Total credit facility amount		$ 600			600
Debt Instrument, Term		5 years
Parent Company [Member]
Line of Credit Facility [Abstract]
Total credit facility amount		$ 1,600			1,200
Debt Instrument, Term		5 years
Revolving Credit Facility [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		$ 0			200
Revolving Credit Facility [Member] | CenterPoint Houston [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		0			$ 200	[1]
Debt, Weighted Average Interest Rate					1.637%
Revolving Credit Facility [Member] | CERC Corp [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		$ 0			0
Line of Credit [Member] | CenterPoint Houston [Member]
Line of Credit Facility [Abstract]
Percentage on limitation of debt to total capitalization under covenant		65.00%
Ratio of Indebtedness to Net Capital		0.527
Percentage on limitation of debt to total capitalization under covenant amended		70.00%
System restoration costs threshold for increase in permitted debt to EBITDA covenant ratio		$ 100
Consecutive Period for System Restoration Costs to Exceed $100 million (in months)		12
Line of Credit [Member] | CenterPoint Houston [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Abstract]
Basis Spread on LIBOR		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		0.307
Line of Credit [Member] | CERC Corp [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Abstract]
Basis Spread on LIBOR		1.25%
Line of Credit [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Percentage on limitation of debt to total capitalization under covenant		65.00%
Ratio of Indebtedness to Net Capital		0.555
Percentage on limitation of debt to total capitalization under covenant amended		70.00%
System restoration costs threshold for increase in permitted debt to EBITDA covenant ratio		$ 100
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		1.25%
Letter of Credit [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		$ 13			12
Letter of Credit [Member] | CenterPoint Houston [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		4			4
Letter of Credit [Member] | CERC Corp [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		3			2
Letter of Credit [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		6			6
Commercial Paper [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit		1,213			935
Commercial Paper [Member] | CenterPoint Houston [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	[2]	$ 176			$ 219
Debt, Weighted Average Interest Rate		0.68%			0.81%
Commercial Paper [Member] | Parent Company [Member]
Line of Credit Facility [Abstract]
Long-term Line of Credit	[3]	$ 1,037			$ 716
Debt, Weighted Average Interest Rate		0.82%			0.79%
Product Financing Arrangement [Member]
Short-term Debt [Line Items]
Total short term borrowings		$ 17			$ 40
Senior Notes [Member] | CERC Corp [Member]
Debt Instruments [Abstract]
Debt Instrument, Face Amount				$ 325
Debt Instrument, Interest Rate, Stated Percentage				6.15%
Bonds General Mortgage Due 2021 [Member] | CenterPoint Houston [Member]
Debt Instruments [Abstract]
Debt Instrument, Face Amount			$ 300
Debt Instrument, Interest Rate, Stated Percentage			1.85%

[1] Weighted average interest rate was 1.637% as of December 31, 2015.

[2] Weighted average interest rate was 0.68% and 0.81% as of June 30, 2016 and December 31, 2015, respectively.

[3] Weighted average interest rate was 0.82% and 0.79% as of June 30, 2016 and December 31, 2015, respectively.

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Income Taxes (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Effective Income Tax Rate Reconciliation, Percent	125.00%	32.00%	39.00%	36.00%

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Commitments and Contingencies (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
GenOn Demand Charges Transportation Contracts [Member] | CERC Corp [Member]
Guarantees
Approximate amount of undiscounted maximum obligation under guarantee	$ 20
CenterPoint Midstream Guarantees [Member]
Guarantees
Approximate amount of undiscounted maximum obligation under guarantee	50
Enable Guaranteed Senior Notes [Member] | CERC Corp [Member]
Guarantees
Approximate amount of undiscounted maximum obligation under guarantee	1,100
Minnesota Service Territory [Member] | CERC Corp [Member]
Environmental Matters
Liability recorded for remediation of Minnesota sites	7
Minnesota Service Territory [Member] | CERC Corp [Member] | Minimum [Member]
Environmental Matters
Estimated remediation costs for the Minnesota sites	$ 4
Site Contingency, Years to Resolve Contingency	30 years
Minnesota Service Territory [Member] | CERC Corp [Member] | Maximum [Member]
Environmental Matters
Estimated remediation costs for the Minnesota sites	$ 30
Site Contingency, Years to Resolve Contingency	50 years
Natural Gas Supply Commitments [Member]
Natural Gas Supply Commitments
2016	$ 190
2017	473
2018	456
2019	270
2020	132
After 2020	$ 127

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Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2016		Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net income (loss)	$ (2)		$ 77	$ 152	$ 208
Basic weighted average shares outstanding	430,653,000		430,235,000	430,530,000	430,096,000
Plus: Incremental shares from assumed conversions:
Diluted weighted average shares	430,653,000		431,733,000	432,973,000	431,594,000
Basic earnings (loss) per share
Net income (loss)	$ (0.01)		$ 0.18	$ 0.35	$ 0.48
Diluted earnings (loss) per share
Net income (loss)	$ (0.01)		$ 0.18	$ 0.35	$ 0.48
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,443,000
Plus: Incremental shares from assumed conversions:
Restricted stock	0	[1]	1,498,000	2,443,000	1,498,000

[1] 2,443,000 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 months ended June 30, 2016, 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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Revenues		$ 1,574	$ 1,532	$ 3,558	$ 3,965
Operating Income		182	186	432	442
Assets		21,012		21,012		$ 21,290
Equity in earnings of unconsolidated affiliate, net		31	43	91	95
Investment in unconsolidated affiliate		2,536		2,536		2,594
Electric Transmission and Distribution [Member]
Segment Reporting Information [Line Items]
Revenues	[1]	763	705	1,423	1,317
Operating Income		158	158	241	254
Electric Transmission and Distribution [Member] | Affiliates of NRG Energy, Inc. [Member]
Segment Reporting Information [Line Items]
Revenues		159	172	304	356
Electric Transmission and Distribution [Member] | Affiliates of Energy Future Holdings Corp. [Member]
Segment Reporting Information [Line Items]
Revenues		50	51	95	103
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Revenues		414	420	1,302	1,605
Operating Income		20	19	180	165
Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		393	404	825	1,036
Operating Income		0	9	6	22
Midstream Investments [Member]
Segment Reporting Information [Line Items]
Revenues	[2]	0	0	0	0
Operating Income	[2]	0	0	0	0
Other Operations [Member]
Segment Reporting Information [Line Items]
Revenues		4	3	8	7
Operating Income		4	0	5	1
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues		(11)	(11)	(25)	(37)
Assets		(918)		(918)		(725)
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		(7)	(7)	(14)	(15)
Intersegment Eliminations [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Revenues		(4)	(4)	(11)	(22)
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		10,065		10,065		10,028
Operating Segments [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Assets		5,585		5,585		5,657
Operating Segments [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Assets		973		973		857
Operating Segments [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Assets	[2]	2,536		2,536		2,594
Operating Segments [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Assets	[3]	2,771		2,771		2,879
Enable Midstream Partners [Member]
Segment Reporting Information [Line Items]
Investment in unconsolidated affiliate		2,536		2,536		2,594
Enable Midstream Partners [Member] | Midstream Investments [Member]
Segment Reporting Information [Line Items]
Equity in earnings of unconsolidated affiliate, net		31	$ 43	91	$ 95
Investment in unconsolidated affiliate		2,536		2,536		2,594
Pension and Other Postretirement Plans Costs [Member] | Other Operations [Member]
Segment Reporting Information [Line Items]
Regulatory Assets		$ 791		$ 791		$ 814

[1] (1)Electric Transmission & Distribution revenues from major customers are as follows: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 (in millions)Affiliates of NRG $159 $172 $304 $356Affiliates of Energy Future Holdings Corp. $50 $51 $95 $103

[2] (2)Midstream Investments’ equity earnings are as follows: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 (in millions)Enable $31 $43 $91 $95Midstream Investments’ total assets are as follows: June 30, 2016 December 31, 2015 (in millions)Enable $2,536 $2,594

[3] Included in total assets of Other Operations as of June 30, 2016 and December 31, 2015 are pension and other postemployment-related regulatory assets of $791 million and $814 million, respectively.

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Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions			3 Months Ended		6 Months Ended
	Aug. 02, 2016	Jul. 28, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Subsequent Event [Line Items]
Common Stock, Dividends, Per Share, Declared			$ 0.2575	$ 0.2475	$ 0.5150	$ 0.4950
Enable Midstream Partners [Member]
Subsequent Event [Line Items]
Proceeds from Equity Method Investment, Dividends or Distributions			$ 75	$ 73	$ 149	$ 145
Subsequent Event [Member]
Subsequent Event [Line Items]
Dividends Payable, Date Declared		Jul. 28, 2016
Common Stock, Dividends, Per Share, Declared		$ 0.2575
Dividends Payable, Date to be Paid, Day, Month and Year		Sep. 09, 2016
Dividends Payable, Date of Record, Day, Month and Year		Aug. 16, 2016
Subsequent Event [Member] | Enable Midstream Partners [Member] | Common Stock [Member]
Subsequent Event [Line Items]
Dividends Payable, Date Declared	Aug. 02, 2016
Common Stock, Dividends, Per Share, Declared	$ 0.318
Proceeds from Equity Method Investment, Dividends or Distributions	$ 74
Subsequent Event [Member] | Enable Midstream Partners [Member] | Redeemable Preferred Stock [Member]
Subsequent Event [Line Items]
Dividends Payable, Date Declared	Aug. 02, 2016
Preferred Stock, Dividends Per Share, Declared	$ 0.625
Proceeds from Equity Method Investment, Dividends or Distributions	$ 9