Centerpoint Energy Resources 10-Q 11 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document (USD $)	6 Months Ended
	Jun. 30, 2014	Jul. 24, 2014	Jun. 30, 2013
Entity Information [Line Items]	'	'	'
Entity Registrant Name	'CENTERPOINT ENERGY RESOURCES CORP	'	'
Entity Central Index Key	'0001042773	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Document Type	'10-Q	'	'
Document Period End Date	30-Jun-14	'	'
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'Q2	'	'
Amendment Flag	'false	'	'
Entity Common Stock, Shares Outstanding	'	1,000	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$0

CONDENSED_STATEMENTS_OF_CONSOL

CONDENSED STATEMENTS OF CONSOLIDATED INCOME (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues	$1,183	$1,235	$3,714	$3,088
Expenses:	'	'	'	'
Natural gas	880	880	2,923	2,104
Operation and maintenance	179	209	378	460
Depreciation and amortization	51	56	100	133
Taxes other than income taxes	34	34	86	85
Total	1,144	1,179	3,487	2,782
Operating Income	39	56	227	306
Other Income (Expense):	'	'	'	'
Interest and other finance charges	-34	-37	-69	-82
Equity in earnings of unconsolidated affiliates, net	71	37	162	42
Other, net	2	-5	4	-5
Total	39	-5	97	-45
Income Before Income Taxes	78	51	324	261
Income tax expense	30	213	124	295
Net Income (Loss)	$48	($162)	$200	($34)

CONDENSED_STATEMENTS_OF_CONSOL1

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net income (Loss)	$48	($162)	$200	($34)
Comprehensive income (Loss)	$48	($162)	$200	($34)

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$5	$1
Accounts receivable, less bad debt reserve of $23 and $25, respectively	486	565
Accrued unbilled revenue	83	311
Accounts and notes receivable — affiliated companies	171	44
Materials and supplies	41	34
Natural gas inventory	140	145
Non-trading derivative assets	26	24
Taxes receivable	0	18
Deferred income tax assets	16	21
Prepaid expenses and other current assets	93	51
Total current assets	1,061	1,214
Property, Plant and Equipment:	'	'
Property, plant and equipment	5,052	4,815
Less: accumulated depreciation and amortization	1,460	1,379
Property, plant and equipment, net	3,592	3,436
Other Assets:	'	'
Goodwill	840	840
Non-trading derivative assets	12	10
Investment in unconsolidated affiliates	4,517	4,518
Notes receivable from unconsolidated affiliates	363	363
Other	145	161
Total other assets	5,877	5,892
Total Assets	10,530	10,542
Current Liabilities:	'	'
Short-term borrowings	42	43
Accounts payable	326	495
Accounts and notes payable — affiliated companies	69	103
Taxes accrued	42	74
Interest accrued	36	36
Customer deposits	78	78
Non-trading derivative liabilities	12	17
Other	155	163
Total current liabilities	760	1,009
Other Liabilities:	'	'
Deferred Tax Liabilities, Net, Noncurrent	2,195	2,082
Non-trading derivative liabilities	2	4
Benefit obligations	103	102
Regulatory liabilities	685	642
Other	156	160
Total other liabilities	3,141	2,990
Long-Term Debt	2,125	2,240
Commitments and Contingencies (Note 10)	'	'
Stockholder’s Equity:	'	'
Common stock	0	0
Paid-in capital	2,417	2,416
Retained earnings	2,082	1,882
Accumulated other comprehensive income	5	5
Total stockholder’s equity	4,504	4,303
Total Liabilities and Stockholder’s Equity	$10,530	$10,542

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS Balance Sheets Parenthetical (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Allowance for Doubtful Accounts Receivable, Current	$23	$25

CONDENSED_STATEMENTS_OF_CONSOL2

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (Unaudited) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash Flows from Operating Activities:	'	'
Net income (loss)	$200	($34)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation and amortization	100	133
Amortization of deferred financing costs	5	6
Deferred income taxes	116	289
Write-down of natural gas inventory	0	3
Equity in earnings of unconsolidated affiliates, net of distributions	2	-25
Changes in other assets and liabilities:	'	'
Accounts receivable and unbilled revenues, net	289	168
Accounts receivable/payable - affiliated companies	18	-10
Inventory	-2	-1
Taxes receivable	18	0
Accounts payable	-174	-109
Fuel cost recovery	-42	116
Interest and taxes accrued	-32	-22
Non-trading derivatives, net	-11	0
Margin deposits, net	-2	7
Other current assets	13	15
Other current liabilities	-11	-17
Other assets	13	-7
Other liabilities	29	14
Other, net	3	1
Net cash provided by operating activities	532	527
Cash Flows from Investing Activities:	'	'
Capital expenditures	-227	-239
Increase in notes receivable from unconsolidated affiliates	-141	0
Investment in unconsolidated affiliates	-1	0
Cash contribution to Enable	0	-38
Other, net	-3	0
Net cash used in investing activities	-372	-277
Cash Flows from Financing Activities:	'	'
Decrease in short-term borrowings, net	-1	-1
Payments of commercial paper, net	-118	0
Proceeds from long-term debt	0	1,050
Payments of long-term debt	0	-525
Decrease in notes payable - affiliated companies	-38	-768
Other, net	1	0
Net cash used in financing activities	-156	-244
Net Increase in Cash and Cash Equivalents	4	6
Cash and Cash Equivalents at Beginning of Period	1	1
Cash and Cash Equivalents at End of Period	5	7
Cash Payments:	'	'
Interest, net of capitalized interest	64	85
Income taxes (refunds), net	-1	1
Non-cash transactions:	'	'
Accounts payable related to capital expenditures	$26	$33

Background_and_Basis_of_Presen

Background and Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Background and Basis of Presentation	'
	Background and Basis of Presentation
	General. Included in this Quarterly Report on Form 10-Q (Form 10-Q) of CenterPoint Energy Resources Corp. (CERC Corp.) are the condensed consolidated interim financial statements and notes (Interim Condensed Financial Statements) of CenterPoint Energy Resources Corp. and its subsidiaries (collectively, CERC).  The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the Annual Report on Form 10-K of CERC Corp. for the year ended December 31, 2013.
	Background. CERC owns and operates natural gas distribution systems (Gas Operations) and owns an interest in Enable Midstream Partners, LP (Enable) as described in Note 6. 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 gas utilities. As of June 30, 2014, 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.
	CERC Corp. is an indirect wholly owned subsidiary of CenterPoint Energy, Inc. (CenterPoint Energy), a public utility holding company.
	Basis of Presentation. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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.
	CERC’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 CERC’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 CERC’s reportable business segments, see Note 12.

New_Accounting_Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	'
	New Accounting Pronouncements
	In April 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2014-08 (ASU 2014-08), Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, which significantly changes the existing accounting guidance on discontinued operations. Under ASU 2014-08, only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results should be reported as a discontinued operation.  ASU 2014-08 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2014.  ASU 2014-08 should be applied to components classified as held for sale after its effective date. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. The adoption is expected to reduce the number of disposals that meet the definition of a discontinued operation.
	In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (ASU 2014-09), which supersedes most current revenue recognition guidance. ASU 2014-09 provides a comprehensive new revenue recognition model that requires revenue to be recognized in a manner that depicts the transfer of goods or services to a customer at an amount that reflects the consideration expected to be received in exchange for those goods or services. ASU 2014-09 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early adoption is not permitted, and entities have the option of using either a full retrospective or a modified retrospective adoption approach. Accordingly, CERC will adopt ASU 2014-09 on January 1, 2017, and is currently evaluating 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 CERC’s consolidated financial position, results of operations or cash flows upon adoption.

Employee_Benefit_Plans_Employe

Employee Benefit Plans Employee Benefit Plans	6 Months Ended
	Jun. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Pension and Other Postretirement Benefits Disclosure [Text Block]	'
	Employee Benefit Plans
	CERC’s employees participate in CenterPoint Energy’s postretirement benefit plan. CERC’s net periodic cost includes the following components relating to postretirement benefits:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in millions)
	Interest cost on accumulated benefit obligation	$	2	$	1	3		2
	Amortization of prior service cost	—		—		—		1
	Amortization of loss	—		1		—		1
	Net periodic cost	$	2	$	2	$	3	$	4
	CERC expects to contribute approximately $7 million to its postretirement benefit plan in 2014, of which $1 million and $3 million was contributed during the three and six months ended June 30, 2014, respectively.

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	CERC is exposed to various market risks. These risks arise from transactions entered into in the normal course of business.  CERC 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 CERC’s Consolidated Balance Sheets at their fair value unless CERC 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 all commodity price, weather and credit risk activities, including CERC’s marketing, risk management services and hedging activities. The committee’s duties are to establish CERC’s commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions and ensure compliance with CERC’s risk management policies and procedures and limits established by CenterPoint Energy’s board of directors.
	CERC’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. CERC 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. CERC has weather normalization or other rate mechanisms that mitigate the impact of weather on its gas operations in Arkansas, Louisiana, Mississippi and Oklahoma. Gas operations in Texas and Minnesota do not have such mechanisms. As a result, fluctuations from normal weather may have a significant positive or negative effect on Gas Operations’ results in these jurisdictions.
	CERC entered into heating-degree day swaps for certain Gas Operations 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 $15 million in 2012 - 2013 and $16 million in 2013 - 2014.  The swaps are based on ten-year normal weather. During the three months ended June 30, 2014 and 2013, CERC recognized losses of $-0- and $3 million, respectively, related to these swaps. During the six months ended June 30, 2014 and 2013, CERC recognized losses of $7 million and $6 million, respectively, related to these swaps. Weather hedge gains and losses are included in revenues in the Condensed Statements of Consolidated Income.
	(b) Derivative Fair Values and Income Statement Impacts
	The following tables present information about CERC’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CERC’s Derivative Assets and Liabilities as of June 30, 2014 and December 31, 2013, while the last two tables provide a breakdown of the related income statement impacts for the three and six months ended June 30, 2014 and 2013.
	Fair Value of Derivative Instruments
					June 30, 2014
	Total derivatives not designated		Balance Sheet		Derivative				Derivative
	as hedging instruments		Location		Assets				Liabilities
					Fair Value				Fair Value
					(in millions)
	Natural gas derivatives (1) (2)		Current Assets: Non-trading derivative assets		$	31			$	5
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		14				2
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		1				13
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		—				2
	Total				$	46			$	22
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 603 Bcf or a net 97 Bcf long position.  Of the net long position, basis swaps constitute 97 Bcf.
	-2	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $24 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above.
	Offsetting of Natural Gas Derivative Assets and Liabilities
			June 30, 2014
			Gross Amounts Recognized (1)				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amount Presented in the Consolidated Balance Sheets (2)
			(in millions)
	Current Assets: Non-trading derivative assets		$	32			$	(6	)		$	26
	Other Assets: Non-trading derivative assets		14				(2		)		12
	Current Liabilities: Non-trading derivative liabilities		(18		)		6				(12		)
	Other Liabilities: Non-trading derivative liabilities		(4		)		2				(2		)
	Total		$	24			$	—			$	24
	________________
	-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 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, 2013
	Total derivatives not designated		Balance Sheet		Derivative				Derivative
	as hedging instruments		Location		Assets				Liabilities
					Fair Value				Fair Value
					(in millions)
	Natural gas derivatives (1) (2) (3)		Current Assets: Non-trading derivative assets		$	28			$	4
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		10				—
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		4				21
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		1				5
	Total				$	43			$	30
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 607  billion cubic feet (Bcf) or a net 46 Bcf long position.  Of the net long position, basis swaps constitute 99 Bcf.
	-2	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $13 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of less than $1 million.
	-3	The $28 million Derivative Current Asset includes $1 million related to physical forwards purchased from Enable.
	Offsetting of Natural Gas Derivative Assets and Liabilities
			December 31, 2013
			Gross Amounts Recognized (1)				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amount Presented in the Consolidated Balance Sheets (2)
			(in millions)
	Current Assets: Non-trading derivative assets		$	32			$	(8	)		$	24
	Other Assets: Non-trading derivative assets		11				(1		)		10
	Current Liabilities: Non-trading derivative liabilities		(25		)		8				(17		)
	Other Liabilities: Non-trading derivative liabilities		(5		)		1				(4		)
	Total		$	13			$	—			$	13
	________________
	-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 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 derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for physical natural gas sales derivative contracts and as natural gas expense for financial natural gas derivatives and other physical natural gas derivatives.
Income Statement Impact of Derivative Activity
				Three Months Ended June 30,
Total derivatives not designated		Income Statement Location		2014				2013
as hedging instruments
				(in millions)
Natural gas derivatives		Gains (Losses) in Revenue		$	5			$	27
Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		4				(18		)
Total				$	9			$	9
Income Statement Impact of Derivative Activity
				Six Months Ended June 30,
Total derivatives not designated		Income Statement Location		2014				2013
as hedging instruments
				(in millions)
Natural gas derivatives		Gains (Losses) in Revenue		$	(96	)		$	13
Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		114				(2		)
Total				$	18			$	11
________________
-1	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and six months ended June 30, 2014 related to physical forwards purchased from Enable.
(c) Credit Risk Contingent Features
CERC enters into financial derivative contracts containing material adverse change provisions.  These provisions could require CERC to post additional collateral if the Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. credit ratings of CERC are downgraded.  The total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position at both June 30, 2014 and December 31, 2013 was $1 million.  The aggregate fair value of assets that were posted as collateral was less than $1 million at both June 30, 2014 and December 31, 2013.  If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered at June 30, 2014 and December 31, 2013, less than $1 million and $1 million, respectively, of additional assets would be required to be posted as collateral.

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures [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 CERC’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 CERC’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. CERC develops these inputs based on the best information available, including CERC’s own data. A market approach is utilized to value CERC’s Level 3 assets or liabilities. Currently, CERC’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 $2.62 to $4.98 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 62%) as an unobservable input.  CERC’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, CERC’s long forwards lose value whereas its short forwards gain in value.  If volatility decreases, CERC’s long options lose value whereas its short options gain in value.
	CERC 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, 2014, there were no transfers between Level 1 and 2. CERC 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 CERC’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2014 and December 31, 2013, and indicate the fair value hierarchy of the valuation techniques utilized by CERC to determine such fair value.
		Quoted Prices in		Significant Other		Significant			Netting			Balance as of June 30, 2014
		Active Markets		Observable		Unobservable			Adjustments (1)
		for Identical Assets		Inputs		Inputs
		(Level 1)		(Level 2)		(Level 3)
		(in millions)
	Assets
	Corporate equities	$	2	$	—	$	—		$	—		$	2
	Investments, including money	11		—		—			—			11
	market funds
	Natural gas derivatives	3		37		6			(8		)	38
	Total assets	$	16	$	37	$	6		$	(8	)	$	51
	Liabilities
	Natural gas derivatives	$	1	$	19	$	2		$	(8	)	$	14
	Total liabilities	$	1	$	19	$	2		$	(8	)	$	14
	________________
	-1	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of $-0- posted with the same counterparties.
		Quoted Prices in		Significant Other		Significant			Netting			Balance as of December 31, 2013
		Active Markets		Observable		Unobservable			Adjustments (1)
		for Identical Assets		Inputs		Inputs
		(Level 1)		(Level 2)		(Level 3)
		(in millions)
	Assets
	Corporate equities	$	2	$	—	$	—		$	—		$	2
	Investments, including money	11		—		—			—			11
	market funds
	Natural gas derivatives (2)	5		33		5			(9		)	34
	Total assets	$	18	$	33	$	5		$	(9	)	$	47
	Liabilities
	Natural gas derivatives	$	1	$	27	$	2		$	(9	)	$	21
	Total liabilities	$	1	$	27	$	2		$	(9	)	$	21
	________________
	-1	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of less than $1 million posted with the same counterparties.
	-2	The (Level 2) Natural gas derivative assets of $33 million includes $1 million related to physical forwards purchased from 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 CERC 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,
		2014		2013		2014			2013
		(in millions)
	Beginning balance	$	1	$	3	$	3		$	2
	Total gains	2		1		—			3
	Total settlements	1		—		2			(1		)
	Transfers into Level 3	—		—		(1		)	—
	Ending balance (1)	$	4	$	4	$	4		$	4
	The amount of total gains for the period included	$	1	$	2	$	2		$	3
	in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date
	____________
	-1	CERC did not have significant Level 3 purchases, sales or transfers out of Level 3 during the three or six months ended June 30, 2014 or 2013.
	Estimated Fair Value of Financial Instruments
	The fair values of cash and cash equivalents and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. Non-trading derivative assets and liabilities 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, 2014				December 31, 2013
		Carrying		Fair		Carrying			Fair
		Amount		Value		Amount			Value
		(in millions)
	Financial assets:
Notes receivable from unconsolidated affiliates	$	363	$	369	$	363		$	363
Financial liabilities:
Long-term debt	$	2,125	$	2,466	$	2,240		$	2,466

Unconsolidated_Affiliates_Note

Unconsolidated Affiliates (Notes)	6 Months Ended
	Jun. 30, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments and Joint Ventures Disclosure [Text Block]	'
	Unconsolidated Affiliates
	On May 1, 2013 (the Closing Date) CERC Corp., OGE Energy Corp. (OGE) and ArcLight Capital Partners, LLC (ArcLight) closed on the formation of Enable. CERC has the ability to significantly influence the operating and financial policies of Enable and, accordingly, accounts for its investment in Enable using the equity method of accounting. Under the equity method, CERC will adjust its investment in Enable each period for contributions made, distributions received, CERC’s share of Enable’s comprehensive income and accretion of differences, as appropriate. CERC evaluates its equity method investments for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.
	CERC’s investment in Enable is considered to be a variable interest entity (VIE) because the power to direct the activities that most significantly impact Enable’s economic performance does not reside with the holders of equity investment at risk. However, CERC is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. CERC’s maximum exposure to loss related to Enable is limited to its equity investment as presented in the Condensed Consolidated Balance Sheet at June 30, 2014, CERC Corp.’s guarantee of collection of Enable’s $1.1 billion senior notes due 2019 and 2024 (Guaranteed Senior Notes) and other guarantees discussed in Note 10, CERC Corp.’s $363 million notes receivable from Enable and outstanding current accounts receivable from Enable. CERC Corp.’s guarantee of Enable’s Guaranteed Senior Notes is subordinated to all senior debt of CERC and is subject to automatic release on May 1, 2016. The $363 million of notes receivable from Enable bears interest at an annual rate of 2.10% to 2.45% and matures in 2017. CERC recorded interest income of $2 million and $1 million during the three months ended June 30, 2014 and 2013, respectively, and $4 million and $1 million during the six months ended June 30, 2014 and 2013, respectively, for interest earned on or after the Closing Date and had interest receivable from Enable of $5 million and $4 million as of June 30, 2014 and December 31, 2013, respectively, on its notes receivable from Enable.
	Effective on the Closing Date, CenterPoint Energy and Enable entered into a Services Agreement, Employee Transition Agreement, Transitional Services Agreement and other agreements (collectively, Transition Agreements) whereby CERC agreed to provide certain support services to Enable such as accounting, legal, risk management and treasury functions for an initial term ending on April 30, 2016. The support services automatically extend year-to-year at the end of the initial term, unless terminated by Enable with at least 90 days’ notice. Enable may terminate the initial support services at any time with 180 days’ notice if approved by the board of Enable's general partner.  Additionally, CERC agreed to provide seconded employees to Enable to support its operations for an initial term ending on December 31, 2014, unless revised by mutual agreement with CERC, OGE and Enable prior to that date.
	CERC billed Enable for reimbursement of transitional services, including the costs of seconded employees, $37 million and $28 million during the three months ended June 30, 2014 and 2013, respectively, and $82 million and $28 million during the six months ended June 30, 2014 and 2013, respectively, under the Transition Agreements for transition services incurred on or after the Closing Date. Actual transitional services costs are recorded net of reimbursements received from Enable. Effective April 1, 2014, Enable’s general partner, CERC and OGE agreed to reduce certain governance related costs billed to Enable for transition services.  CERC had accounts receivable from Enable of $20 million and $21 million as of June 30, 2014 and December 31, 2013, respectively, for amounts billed for transitional services, including the cost of seconded employees.
	Enable, at its discretion, has the right to select and offer employment to seconded employees from CERC. CERC did not transfer any employees to Enable at formation of the partnership or at any time during the period from the Closing Date through June 30, 2014. As of June 30, 2014, CERC determined it cannot reasonably estimate the impact of the costs associated with the termination of employees related to the formation of Enable or transfer of employees from CERC to Enable, including the impact of the changes to the actuarial determination of employee benefit plan obligations. Pursuant to the Transition Agreements, Enable has agreed to reimburse CERC for severance and termination costs related to the termination of CERC's seconded employees, regardless of whether such seconded employees are offered employment by Enable.
	On April 16, 2014, Enable completed its initial public offering (IPO) of 28,750,000 common units, at a price of $20.00 per unit, which included 3,750,000 common units sold by ArcLight pursuant to an over-allotment option that was fully exercised by the underwriters. Enable received $464 million in net proceeds from the sale of the units, after deducting underwriting fees, structuring fees and other offering costs. In connection with Enable’s IPO, a portion of CERC’s common units were converted into subordinated units, as discussed further below. Subsequent to the IPO, Enable continues to be equally controlled by CERC and OGE; each own 50% of the management rights in the general partner of Enable. CERC and OGE also own a 40% and 60% economic interest, respectively, in the incentive distribution rights held by the general partner of Enable.
	As a result of Enable’s IPO, CERC’s limited partner interest in Enable was reduced from approximately 58.3% to approximately 54.7%. CERC accounted for the dilution of its investment in Enable as a result of Enable’s IPO as a failed partial sale of in-substance real estate. CERC did not receive any cash from Enable’s IPO and, as such, CERC did not recognize a gain or loss. CERC’s basis difference in Enable was reduced for the impact of the Enable IPO.
	In accordance with the Enable formation agreements, CERC had certain put rights, and Enable had certain call rights, exercisable with respect to the 25.05% interest in Southeast Supply Header, LLC (SESH) retained by CERC, under which CERC would contribute its retained interest in SESH, in exchange for a specified number of limited partner units in Enable and a cash payment, payable either from CERC to Enable or from Enable to CERC, to the extent of changes in the value of SESH subject to certain restrictions. Specifically, the rights were and are exercisable with respect to (1) a 24.95% interest in SESH (24.95% Put), which closed on May 30, 2014 as discussed below and (2) a 0.1% interest in SESH, which may be exercised no earlier than June 2015 for 25,341 common units in Enable.
	On May 30, 2014, CERC closed its 24.95% Put and contributed to Enable its 24.95% interest in SESH in exchange for 6,322,457 common units of Enable, which increased CERC's limited partner interest in Enable from approximately 54.7% to approximately 55.4%. No cash payment was required to be made pursuant to the Enable formation agreements in connection with CERC's exercise of the 24.95% Put. CERC accounted for the contribution of its 24.95% interest in SESH to Enable in exchange for common units of Enable as a non-monetary transaction of in-substance real estate equity method investments. As such, CERC recorded the 6,322,457 common units at the historical cost of the contributed 24.95% interest in SESH of $198 million and recorded no gain or loss in connection with its exercise of the 24.95% Put. As a result, CERC's basis difference in Enable was reduced for the impact of its exercise of the 24.95% Put.
	CERC incurred natural gas expenses, including transportation and storage costs, of $27 million and $28 million, during the three months ended June 30, 2014 and 2013, respectively, and $75 million and $28 million during the six months ended June 30, 2014 and 2013, respectively, for transactions with Enable occurring on or after the Closing Date. CERC had accounts payable to Enable of $15 million and $22 million at June 30, 2014 and December 31, 2013, respectively, from such transactions.
	As of June 30, 2014, CERC held an approximate 55.4% limited partner interest in Enable consisting of 94,126,366 common units and 139,704,916 subordinated units and a 0.1% interest in SESH. The principal difference between Enable common units and subordinated units is that in any quarter during the subordination period, holders of the subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. If Enable does not pay distributions on its subordinated units, the subordinated units will not accrue arrearages for those unpaid distributions. At the end of the subordination period, CERC’s subordinated units in Enable will be converted to common units in Enable on a one-for-one basis. On June 30, 2014, Enable’s common units closed at $26.19 per unit on the New York Stock Exchange.
	Investment in Unconsolidated Affiliates:
			June 30, 2014			December 31, 2013
			(in millions)
	Enable		$	4,517		$	4,319
	SESH (1)		—			199
	Total		$	4,517		$	4,518
	-1	On May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.
	Equity in Earnings of Unconsolidated Affiliates, net:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	69		$	33		$	157	$	33
	SESH (2)		2			4			5		9
			$	71		$	37		$	162	$	42
	-1	On May 1, 2013, CERC formed Enable with OGE and ArcLight.
	-2	On each of May 1, 2013 and May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.
	Summarized unaudited consolidated income information for Enable is as follows:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013 (1)			2014		2013 (1)
			(in millions)
	Operating revenues		$	826		$	502		$	1,828	$	502
	Cost of sales, excluding depreciation and amortization		478			295			1,111		295
	Operating income		139			75			301		75
	Net income attributable to Enable		120			65			269		65
	CERC's approximate interest		$	67		$	38		$	154	$	38
	Basis difference accretion (amortization)		2			(5		)	3		(5		)
	CERC's equity in earnings, net		$	69		$	33		$	157	$	33
	-1	The summarized income information for Enable and CERC’s equity in earnings, net of basis difference amortization, presented for the three and six months ended June 30, 2013 reflects Enable’s operating results with the contributions from both OGE and CERC recorded at historical cost for the two-month period from the Closing Date to June 30, 2013.
	Enable concluded that its formation was considered a business combination, in which the fair value of the consideration paid for Enogex, LLC (Enogex), the businesses contributed by OGE, was allocated to the assets acquired and liabilities assumed by Enable on the Closing Date. In the third quarter of 2013, Enable completed its valuation of Enogex, and Enogex's assets, liabilities and equity, and the related depreciation and amortization for the two-month period ended June 30, 2013, was accordingly adjusted to estimated fair value as of the Closing Date. CERC’s equity in earnings, net of basis difference, in the second quarter of 2013 was not materially different as a result of the final fair value determination.
	Summarized unaudited consolidated balance sheet information for Enable is as follows:
			June 30,			31-Dec-13
			2014
			(in millions)
	Current assets		$	923		$	549
	Non-current assets		10,815			10,683
	Current liabilities		584			720
	Non-current liabilities		2,343			2,331
	Non-controlling interest		32			33
	Enable partners' capital		8,779			8,148
	CERC's ownership interest in Enable's partner capital		$	4,862		$	4,753
	CERC's basis difference		(345		)	(434		)
	CERC's investment in Enable		$	4,517		$	4,319
	Cash distributions received from Enable and SESH were approximately $90 million and $4 million, respectively, during the three months ended June 30, 2014 and were $-0- and $8 million, respectively, during the three months ended June 30, 2013. Cash distributions received from Enable and SESH were approximately $157 million and $7 million, respectively, during the six months ended June 30, 2014 and were $-0- and $17 million, respectively, during the six months ended June 30, 2013.

Goodwill

Goodwill	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets Disclosure [Text Block]	'
	Goodwill
	Goodwill by reportable business segment as of both June 30, 2014 and December 31, 2013 is as follows (in millions):
	Natural Gas Distribution	$	746
	Energy Services	83
	Other Operations	11
	Total	$	840

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	CERC participates in a “money pool” through which it can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper. CERC had investments in the money pool of $141 million and borrowings from the money pool of $38 million at June 30, 2014 and December 31, 2013, respectively, which are included in accounts and notes receivable — affiliated companies and accounts and notes payable — affiliated companies, respectively, in the Condensed Consolidated Balance Sheets.
	CERC had net interest income of less than $1 million and net interest expense of less than $1 million related to affiliate borrowings for the three and six months ended June 30, 2014, respectively, and net interest expense of less than $1 million and $1 million for the three and six months ended June 30, 2013, respectively.
	CenterPoint Energy provides some corporate services to CERC. The costs of services have been charged directly to CERC using methods that management believes are reasonable. These methods include negotiated usage rates, dedicated asset assignment and proportionate corporate formulas based on operating expenses, assets, gross margin, employees and a composite of assets, gross margin and employees. These charges are not necessarily indicative of what would have been incurred had CERC not been an affiliate of CenterPoint Energy. Amounts charged to CERC for these services were $31 million and $23 million for the three months ended June 30, 2014 and 2013, respectively, and $59 million and $60 million for the six months ended June 30, 2014 and 2013, respectively, and are included primarily in operation and maintenance expenses.

Shortterm_Borrowings_and_Longt

Short-term Borrowings and Long-term Debt

6 Months Ended

Jun. 30, 2014

Debt Disclosure [Abstract]

'

Short-term Borrowings and Long-term Debt

'

Short-term Borrowings and Long-term Debt

(a)Short-term Borrowings

Inventory Financing. Gas Operations has asset management agreements associated with its utility distribution service in Arkansas, north Louisiana and Oklahoma that extend through 2015. Pursuant to the provisions of the agreements, Gas Operations 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 $42 million and $43 million as of June 30, 2014 and December 31, 2013, respectively.

(b)

Long-term Debt

Revolving Credit Facility.   As of June 30, 2014 and December 31, 2013, CERC had the following revolving credit facility and utilization of such facility (in millions):

June 30, 2014

December 31, 2013

Size of

Loans

Letters

Commercial

Loans

Letters

Commercial

Facility

of Credit

Paper

of Credit

Paper

$

600

$

—

$

—

$

—

$

—

$

—

$

118

CERC Corp.’s $600 million revolving credit facility, which is scheduled to terminate on September 9, 2018, can be drawn at the London Interbank Offered Rate plus 150 basis points 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.

CERC Corp. was in compliance with all financial covenants in its revolving credit facility as of June 30, 2014.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	(a) Natural Gas Supply Commitments
	Natural gas supply commitments include natural gas contracts related to CERC’s Natural Gas Distribution and Energy Services business segments, which have various quantity requirements and durations, that are not classified as non-trading derivative assets and liabilities in CERC’s Condensed Consolidated Balance Sheets as of June 30, 2014 and December 31, 2013 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, 2014, minimum payment obligations for natural gas supply commitments are approximately $259 million for the remaining six months in 2014, $528 million in 2015, $454 million in 2016, $384 million in 2017, $376 million in 2018 and $174 million after 2018.
	(b) Legal, Environmental and Other Regulatory Matters
	Legal Matters
	Gas Market Manipulation Cases.  CenterPoint Energy, CenterPoint Energy Houston Electric, LLC or their predecessor, Reliant Energy, Incorporated (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, Reliant Resources, Inc. (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 Energy, Inc. (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 CenterPoint Houston, 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 but one such case. CenterPoint Energy Services, Inc. (CES), a subsidiary of CERC Corp., is a defendant in a case now pending in federal court in Nevada alleging a conspiracy to inflate Wisconsin natural gas prices in 2000-2002.  In July 2011, the court issued an order dismissing the plaintiffs’ claims against other defendants in the case, each of whom had demonstrated Federal Energy Regulatory Commission jurisdictional sales for resale during the relevant period, based on federal preemption.  The plaintiffs appealed this ruling to the United States Court of Appeals for the Ninth Circuit, which reversed the trial court's dismissal of the plaintiffs' claims. In August 2013, the other defendants filed a petition for review with the U.S. Supreme Court, which the court granted on June 30, 2014. CenterPoint Energy believes that CES is not a proper defendant in this case and will continue to pursue a dismissal.  CERC does not expect the ultimate outcome of this matter to have a material impact on its financial condition, results of operations or cash flows.
	Environmental Matters
	Manufactured Gas Plant Sites. CERC and its predecessors operated manufactured gas plants (MGPs) in the past.  There are seven MGP sites in CERC’s Minnesota service territory.  CERC believes it never owned or operated, and therefore has no liability with respect to, two of these sites.  With respect to two other sites, CERC has completed state ordered remediation, other than ongoing monitoring and water treatment.
	At June 30, 2014, CERC had recorded a liability of $13 million for remediation of these Minnesota sites. The estimated range of possible remediation costs for the sites for which CERC believes it may have responsibility was $6 million to $41 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 be dependent upon the number of sites to be remediated, the participation of other potentially responsible parties (PRPs), if any, and the remediation methods used. The Minnesota Public Utilities Commission includes approximately $285,000 annually in rates to fund normal ongoing remediation costs.  As of June 30, 2014, CERC had collected $6 million from insurance companies to be used for future environmental remediation.
	In addition to the Minnesota sites, the United States 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. CERC and CenterPoint Energy do not expect the ultimate outcome of these investigations will have a material adverse impact on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC.
	Asbestos. Some facilities owned by CERC's predecessors contain or have contained asbestos insulation and other asbestos-containing materials. CERC or its predecessor companies have been named, along with numerous others, as a defendant in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos. Some of the claimants have worked at locations owned by CERC, but most existing claims relate to facilities previously owned by CERC's subsidiaries. CERC anticipates that additional claims like those received may be asserted in the future.  Although their ultimate outcome cannot be predicted at this time, CERC intends to continue vigorously contesting claims that it does not consider to have merit and, based on its experience to date, does not expect these matters, either individually or in the aggregate, to have a material adverse effect on its financial condition, results of operations or cash flows.
	Other Environmental. From time to time CERC identifies the presence of environmental contaminants on property where it conducts or has conducted operations. Other such sites involving contaminants may be identified in the future.  CERC has and expects to continue to remediate identified sites consistent with its legal obligations. From time to time CERC 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, CERC 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, CERC does not expect, based on its experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on its financial condition, results of operations or cash flows.
	Other Proceedings
	CERC 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, CERC 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. CERC regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. CERC does not expect the disposition of these matters to have a material adverse effect on its 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 $51 million as of June 30, 2014.  Based on market conditions in the fourth quarter of 2013 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.
	CERC Corp. has also provided a guarantee of collection of $1.1 billion of Enable's Guaranteed Senior Notes. This guarantee is subordinated to all senior debt of CERC Corp. and is subject to automatic release on May 1, 2016.
	As of June 30, 2014, no amounts had been recorded in the Condensed Consolidated Balance Sheets related to these guarantees.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The effective tax rate reported for both the three and six months ended June 30, 2014 was 38% compared to 418% and 113%, respectively, for the same periods in 2013. The higher effective tax rate for the three and six months ended June 30, 2013 was primarily associated with the formation of Enable. As a result of the Enable formation, a deferred tax liability of $225 million was recorded for the book-to-tax basis differences in CERC’s investment resulting from the goodwill that was contributed by CERC. In addition, CERC recognized a tax benefit of $27 million associated with the remeasurement of state deferred taxes related to the Enable formation.
	CERC reported no uncertain tax liability as of June 30, 2014 and expects no significant change to the uncertain tax liability over the next twelve months ending June 30, 2015. CenterPoint Energy’s consolidated federal income tax return filed for the year ended December 31, 2012 is currently under audit by the Internal Revenue Service, and all other consolidated federal income tax returns have been audited and settled through the tax year 2011.

Reportable_Business_Segments

Reportable Business Segments	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Reportable Business Segments	'
	Reportable Business Segments
	Because CERC is an indirect wholly owned subsidiary of CenterPoint Energy, CERC’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. CERC uses operating income as the measure of profit or loss for its business segments.
	CERC’s reportable business segments include the following: Natural Gas Distribution, Energy Services, Midstream Investments and Other Operations.  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 CERC’s non-rate regulated gas sales and services operations. Midstream Investments consists primarily of CERC’s investment in Enable and its retained interest in SESH. The Other Operations business segment includes unallocated corporate costs and inter-segment eliminations.
	Prior to May 1, 2013, CERC also reported an Interstate Pipelines business segment, which included CERC’s interstate natural gas pipeline operations, and a Field Services business segment, which included CERC’s non-rate regulated natural gas gathering, processing and treating operations. The formation of Enable closed on May 1, 2013. Enable now owns substantially all of CERC’s former Interstate Pipelines and Field Services business segments, except for a 0.1% interest in SESH. As a result, effective May 1, 2013, CERC reports equity earnings associated with its interest in Enable and equity earnings associated with its interest in SESH under the Midstream Investments segment, and no longer has Interstate Pipelines and Field Services reporting segments prospectively.
	Financial data for business segments is as follows (in millions):
		For the Three Months Ended June 30, 2014
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	526	$	6		$	30
	Energy Services	657		19			11
	Midstream Investments (1)	—		—			—
	Other	—		—			(2		)
	Reconciling Eliminations	—		(25		)	—
	Consolidated	$	1,183	$	—		$	39
		For the Three Months Ended June 30, 2013
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	524	$	5		$	25
	Energy Services	622		6			3
	Interstate Pipelines (2)	41		13			20
	Field Services (2)	48		7			20
	Midstream Investments (1)	—		—			—
	Other	—		—			(12		)
	Reconciling Eliminations	—		(31		)	—
	Consolidated	$	1,235	$	—		$	56
		For the Six Months Ended June 30, 2014
		Revenues from		Inter-segment			Operating			Total Assets
		External		Revenues			Income (Loss)			as of June 30, 2014
		Customers
	Natural Gas Distribution	$	2,004	$	15		$	192		$	4,989
	Energy Services	1,709		51			37			896
	Midstream Investments (1)	—		—			—			4,517
	Other	1		—			(2		)	889
	Reconciling Eliminations	—		(66		)	—			(761		)
	Consolidated	$	3,714	$	—		$	227		$	10,530
		For the Six Months Ended June 30, 2013
		Revenues from		Inter-segment			Operating			Total Assets as of December 31, 2013
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	1,567	$	13		$	164		$	4,976
	Energy Services	1,210		15			10			895
	Interstate Pipelines (2)	133		53			72			—
	Field Services (2)	178		18			73			—
	Midstream Investments (1)	—		—			—			4,518
	Other	—		—			(13		)	1,149
	Reconciling Eliminations	—		(99		)	—			(996		)
	Consolidated	$	3,088	$	—		$	306		$	10,542
	-1	Midstream Investments reported equity earnings of $69 million from Enable and $2 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the three months ended June 30, 2014. Midstream Investments reported equity earnings of $157 million from Enable and $5 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the six months ended June 30, 2014. Midstream Investments reported equity earnings of $33 million from Enable and $2 million of equity earnings from CenterPoint Energy’s interest in SESH for the months of May and June 2013. Included in total assets of Midstream Investments as of June 30, 2014 and December 31, 2013 is $4,517 million and $4,319 million, respectively, related to CenterPoint Energy’s investment in Enable and $-0- and $199 million, respectively, related to CenterPoint Energy’s interest in SESH.
	-2	Results reflected in the three months ended June 30, 2013 represent only the month of April 2013. Results reflected in the six months ended June 30, 2013 represent only January 2013 through April 2013.

Other_Current_Assets_and_Liabi

Other Current Assets and Liabilities	6 Months Ended
	Jun. 30, 2014
Other Current Assets and Liabilities [Abstract]	'
Other Current Assets and Liabilities [Text Block]	'
	Other Current Assets and Liabilities
	Included in other current assets on the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013 were $6 million and $4 million, respectively, of margin deposits and $71 million and $22 million, respectively, of under-recovered gas cost. Included in other current liabilities on the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013 were $62 million and $42 million, respectively, of over-recovered gas cost.

Employee_Benefit_Plans_Employe1

Employee Benefit Plans Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Schedule of Net Benefit Costs [Table Text Block]	'
	CERC’s employees participate in CenterPoint Energy’s postretirement benefit plan. CERC’s net periodic cost includes the following components relating to postretirement benefits:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in millions)
	Interest cost on accumulated benefit obligation	$	2	$	1	3		2
	Amortization of prior service cost	—		—		—		1
	Amortization of loss	—		1		—		1
	Net periodic cost	$	2	$	2	$	3	$	4

Derivative_Instruments_Derivat

Derivative Instruments Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Fair Value of Derivative Instruments Table	'
	The following tables present information about CERC’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CERC’s Derivative Assets and Liabilities as of June 30, 2014 and December 31, 2013, while the last two tables provide a breakdown of the related income statement impacts for the three and six months ended June 30, 2014 and 2013.
	Fair Value of Derivative Instruments
					June 30, 2014
	Total derivatives not designated		Balance Sheet		Derivative				Derivative
	as hedging instruments		Location		Assets				Liabilities
					Fair Value				Fair Value
					(in millions)
	Natural gas derivatives (1) (2)		Current Assets: Non-trading derivative assets		$	31			$	5
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		14				2
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		1				13
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		—				2
	Total				$	46			$	22
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 603 Bcf or a net 97 Bcf long position.  Of the net long position, basis swaps constitute 97 Bcf.
	-2	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $24 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above.
	Offsetting of Natural Gas Derivative Assets and Liabilities
			June 30, 2014
			Gross Amounts Recognized (1)				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amount Presented in the Consolidated Balance Sheets (2)
			(in millions)
	Current Assets: Non-trading derivative assets		$	32			$	(6	)		$	26
	Other Assets: Non-trading derivative assets		14				(2		)		12
	Current Liabilities: Non-trading derivative liabilities		(18		)		6				(12		)
	Other Liabilities: Non-trading derivative liabilities		(4		)		2				(2		)
	Total		$	24			$	—			$	24
	________________
	-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 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, 2013
	Total derivatives not designated		Balance Sheet		Derivative				Derivative
	as hedging instruments		Location		Assets				Liabilities
					Fair Value				Fair Value
					(in millions)
	Natural gas derivatives (1) (2) (3)		Current Assets: Non-trading derivative assets		$	28			$	4
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		10				—
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		4				21
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		1				5
	Total				$	43			$	30
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 607  billion cubic feet (Bcf) or a net 46 Bcf long position.  Of the net long position, basis swaps constitute 99 Bcf.
	-2	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $13 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of less than $1 million.
	-3	The $28 million Derivative Current Asset includes $1 million related to physical forwards purchased from Enable.
	Offsetting of Natural Gas Derivative Assets and Liabilities
			December 31, 2013
			Gross Amounts Recognized (1)				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amount Presented in the Consolidated Balance Sheets (2)
			(in millions)
	Current Assets: Non-trading derivative assets		$	32			$	(8	)		$	24
	Other Assets: Non-trading derivative assets		11				(1		)		10
	Current Liabilities: Non-trading derivative liabilities		(25		)		8				(17		)
	Other Liabilities: Non-trading derivative liabilities		(5		)		1				(4		)
	Total		$	13			$	—			$	13
	________________
	-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 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	'
	Income Statement Impact of Derivative Activity
					Three Months Ended June 30,
	Total derivatives not designated		Income Statement Location		2014				2013
	as hedging instruments
					(in millions)
	Natural gas derivatives		Gains (Losses) in Revenue		$	5			$	27
	Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		4				(18		)
	Total				$	9			$	9
	Income Statement Impact of Derivative Activity
					Six Months Ended June 30,
	Total derivatives not designated		Income Statement Location		2014				2013
	as hedging instruments
					(in millions)
	Natural gas derivatives		Gains (Losses) in Revenue		$	(96	)		$	13
	Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		114				(2		)
	Total				$	18			$	11
	________________
	-1	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and six months ended June 30, 2014 related to physical forwards purchased from Enable.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	'
	The following tables present information about CERC’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2014 and December 31, 2013, and indicate the fair value hierarchy of the valuation techniques utilized by CERC to determine such fair value.
		Quoted Prices in		Significant Other		Significant			Netting			Balance as of June 30, 2014
		Active Markets		Observable		Unobservable			Adjustments (1)
		for Identical Assets		Inputs		Inputs
		(Level 1)		(Level 2)		(Level 3)
		(in millions)
	Assets
	Corporate equities	$	2	$	—	$	—		$	—		$	2
	Investments, including money	11		—		—			—			11
	market funds
	Natural gas derivatives	3		37		6			(8		)	38
	Total assets	$	16	$	37	$	6		$	(8	)	$	51
	Liabilities
	Natural gas derivatives	$	1	$	19	$	2		$	(8	)	$	14
	Total liabilities	$	1	$	19	$	2		$	(8	)	$	14
	________________
	-1	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of $-0- posted with the same counterparties.
		Quoted Prices in		Significant Other		Significant			Netting			Balance as of December 31, 2013
		Active Markets		Observable		Unobservable			Adjustments (1)
		for Identical Assets		Inputs		Inputs
		(Level 1)		(Level 2)		(Level 3)
		(in millions)
	Assets
	Corporate equities	$	2	$	—	$	—		$	—		$	2
	Investments, including money	11		—		—			—			11
	market funds
	Natural gas derivatives (2)	5		33		5			(9		)	34
	Total assets	$	18	$	33	$	5		$	(9	)	$	47
	Liabilities
	Natural gas derivatives	$	1	$	27	$	2		$	(9	)	$	21
	Total liabilities	$	1	$	27	$	2		$	(9	)	$	21
	________________
	-1	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of less than $1 million posted with the same counterparties.
	-2	The (Level 2) Natural gas derivative assets of $33 million includes $1 million related to physical forwards purchased from Enable.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [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 CERC 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,
		2014		2013		2014			2013
		(in millions)
	Beginning balance	$	1	$	3	$	3		$	2
	Total gains	2		1		—			3
	Total settlements	1		—		2			(1		)
	Transfers into Level 3	—		—		(1		)	—
	Ending balance (1)	$	4	$	4	$	4		$	4
	The amount of total gains for the period included	$	1	$	2	$	2		$	3
	in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date
	____________
	-1	CERC did not have significant Level 3 purchases, sales or transfers out of Level 3 during the three or six months ended June 30, 2014 or 2013.
Fair Value, by Balance Sheet Grouping [Table Text Block]	'
	Estimated Fair Value of Financial Instruments
	The fair values of cash and cash equivalents and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. Non-trading derivative assets and liabilities 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, 2014				December 31, 2013
		Carrying		Fair		Carrying			Fair
		Amount		Value		Amount			Value
		(in millions)
	Financial assets:
	Notes receivable from unconsolidated affiliates	$	363	$	369	$	363		$	363
	Financial liabilities:
	Long-term debt	$	2,125	$	2,466	$	2,240		$	2,466

Unconsolidated_Affiliates_Tabl

Unconsolidated Affiliates (Tables)	6 Months Ended
	Jun. 30, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments [Table Text Block]	'
	Investment in Unconsolidated Affiliates:
			June 30, 2014			December 31, 2013
			(in millions)
	Enable		$	4,517		$	4,319
	SESH (1)		—			199
	Total		$	4,517		$	4,518
	-1	On May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.
	Equity in Earnings of Unconsolidated Affiliates, net:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	69		$	33		$	157	$	33
	SESH (2)		2			4			5		9
			$	71		$	37		$	162	$	42
	-1	On May 1, 2013, CERC formed Enable with OGE and ArcLight.
	-2	On each of May 1, 2013 and May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.
	Summarized unaudited consolidated income information for Enable is as follows:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013 (1)			2014		2013 (1)
			(in millions)
	Operating revenues		$	826		$	502		$	1,828	$	502
	Cost of sales, excluding depreciation and amortization		478			295			1,111		295
	Operating income		139			75			301		75
	Net income attributable to Enable		120			65			269		65
	CERC's approximate interest		$	67		$	38		$	154	$	38
	Basis difference accretion (amortization)		2			(5		)	3		(5		)
	CERC's equity in earnings, net		$	69		$	33		$	157	$	33
	-1	The summarized income information for Enable and CERC’s equity in earnings, net of basis difference amortization, presented for the three and six months ended June 30, 2013 reflects Enable’s operating results with the contributions from both OGE and CERC recorded at historical cost for the two-month period from the Closing Date to June 30, 2013.
	Enable concluded that its formation was considered a business combination, in which the fair value of the consideration paid for Enogex, LLC (Enogex), the businesses contributed by OGE, was allocated to the assets acquired and liabilities assumed by Enable on the Closing Date. In the third quarter of 2013, Enable completed its valuation of Enogex, and Enogex's assets, liabilities and equity, and the related depreciation and amortization for the two-month period ended June 30, 2013, was accordingly adjusted to estimated fair value as of the Closing Date. CERC’s equity in earnings, net of basis difference, in the second quarter of 2013 was not materially different as a result of the final fair value determination.
	Summarized unaudited consolidated balance sheet information for Enable is as follows:
			June 30,			31-Dec-13
			2014
			(in millions)
	Current assets		$	923		$	549
	Non-current assets		10,815			10,683
	Current liabilities		584			720
	Non-current liabilities		2,343			2,331
	Non-controlling interest		32			33
	Enable partners' capital		8,779			8,148
	CERC's ownership interest in Enable's partner capital		$	4,862		$	4,753
	CERC's basis difference		(345		)	(434		)
	CERC's investment in Enable		$	4,517		$	4,319

Goodwill_Goodwill_Tables

Goodwill Goodwill (Tables)	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill [Table Text Block]	'
	Goodwill by reportable business segment as of both June 30, 2014 and December 31, 2013 is as follows (in millions):
	Natural Gas Distribution	$	746
	Energy Services	83
	Other Operations	11
	Total	$	840

Shortterm_Borrowings_and_Longt1

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

6 Months Ended

Jun. 30, 2014

Debt Disclosure [Abstract]

'

Schedule of Line of Credit Facilities [Table Text Block]

'

Revolving Credit Facility.   As of June 30, 2014 and December 31, 2013, CERC had the following revolving credit facility and utilization of such facility (in millions):

June 30, 2014

December 31, 2013

Size of

Loans

Letters

Commercial

Loans

Letters

Commercial

Facility

of Credit

Paper

of Credit

Paper

$

600

$

—

$

—

$

—

$

—

$

—

$

118

Reportable_Business_Segments_T

Reportable Business Segments (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	Financial data for business segments is as follows (in millions):
		For the Three Months Ended June 30, 2014
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	526	$	6		$	30
	Energy Services	657		19			11
	Midstream Investments (1)	—		—			—
	Other	—		—			(2		)
	Reconciling Eliminations	—		(25		)	—
	Consolidated	$	1,183	$	—		$	39
		For the Three Months Ended June 30, 2013
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	524	$	5		$	25
	Energy Services	622		6			3
	Interstate Pipelines (2)	41		13			20
	Field Services (2)	48		7			20
	Midstream Investments (1)	—		—			—
	Other	—		—			(12		)
	Reconciling Eliminations	—		(31		)	—
	Consolidated	$	1,235	$	—		$	56
		For the Six Months Ended June 30, 2014
		Revenues from		Inter-segment			Operating			Total Assets
		External		Revenues			Income (Loss)			as of June 30, 2014
		Customers
	Natural Gas Distribution	$	2,004	$	15		$	192		$	4,989
	Energy Services	1,709		51			37			896
	Midstream Investments (1)	—		—			—			4,517
	Other	1		—			(2		)	889
	Reconciling Eliminations	—		(66		)	—			(761		)
	Consolidated	$	3,714	$	—		$	227		$	10,530
		For the Six Months Ended June 30, 2013
		Revenues from		Inter-segment			Operating			Total Assets as of December 31, 2013
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	1,567	$	13		$	164		$	4,976
	Energy Services	1,210		15			10			895
	Interstate Pipelines (2)	133		53			72			—
	Field Services (2)	178		18			73			—
	Midstream Investments (1)	—		—			—			4,518
	Other	—		—			(13		)	1,149
	Reconciling Eliminations	—		(99		)	—			(996		)
	Consolidated	$	3,088	$	—		$	306		$	10,542
	-1	Midstream Investments reported equity earnings of $69 million from Enable and $2 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the three months ended June 30, 2014. Midstream Investments reported equity earnings of $157 million from Enable and $5 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the six months ended June 30, 2014. Midstream Investments reported equity earnings of $33 million from Enable and $2 million of equity earnings from CenterPoint Energy’s interest in SESH for the months of May and June 2013. Included in total assets of Midstream Investments as of June 30, 2014 and December 31, 2013 is $4,517 million and $4,319 million, respectively, related to CenterPoint Energy’s investment in Enable and $-0- and $199 million, respectively, related to CenterPoint Energy’s interest in SESH.
	-2	Results reflected in the three months ended June 30, 2013 represent only the month of April 2013. Results reflected in the six months ended June 30, 2013 represent only January 2013 through April 2013.

Background_and_Basis_of_Presen1

Background and Basis of Presentation (Details) (Midstream Partnership [Member], CERC Corp [Member])	Jun. 30, 2014	Apr. 16, 2014	Mar. 31, 2014
Midstream Partnership [Member] | CERC Corp [Member]	'	'	'
Equity Method Investment, Ownership Percentage	55.40%	54.70%	58.30%

Employee_Benefit_Plans_Employe2

Employee Benefit Plans Employee Benefit Plans (Details) (Other Postretirement Benefit Plans, Defined Benefit [Member], USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Other Postretirement Benefit Plans, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Interest cost on accumulated benefit obligation	$2	$1	$3	$2
Amortization of prior service cost	0	0	0	1
Amortization of loss	0	1	0	1
Net periodic cost	2	2	3	4
Contribution expected in 2013	'	'	7	'
Contribution made in period	$1	'	$3	'

Derivative_Instruments_Derivat1

Derivative Instruments Derivative Instruments (Details) (USD $)	3 Months Ended				6 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
					MMcf				MMcf
					Years
Derivatives, Fair Value [Line Items]	'		'		'		'		'
Term of normal weather used as the basis for weather hedges (in years)	'		'		10		'		'
Gains (Losses) Recognized Related to Weather Hedges	$0		($3)		($7)		($6)		'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]	'		'		'		'		'
Derivative Asset, Fair Value, Gross Asset	46		'		46		'		43
Derivative Liability, Fair Value, Gross Liability	22		'		22		'		30
Derivative gross volumes on natural gas contracts (MMcf)	'		'		603,000		'		607,000
Net long position (MMcf)	'		'		97,000		'		46,000
Amount of net long position constituted by basis swaps (MMcf)	'		'		97,000		'		99,000
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	9		9		18		11		'
Derivative Instruments, Assets, Physical Forwards Purchased	'		'		'		'		1
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Derivative, fair value, offsets, net	'		'		'		'		1
Net Amount Presented in the Consolidated Balance Sheets (2)	24		'		24		'		13
Total fair value of the derivative instruments that contain credit risk contingency features that are in a net liability position	1		'		1		'		1
Collateral Already Posted, Aggregate Fair Value	1		'		1		'		1
Credit Risk Contingent Feature assets	1		'		1		'		1
Natural Gas Derivatives [Member]	'		'		'		'		'
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Gross Amounts Recognized (1)	24	[1]	'		24	[1]	'		13	[1]
Derivative, fair value, offsets, net	0		'		0		'		0
Net Amount Presented in the Consolidated Balance Sheets (2)	24	[2]	'		24	[2]	'		13	[2]
Natural Gas Derivatives [Member] | Current Assets [Member]	'		'		'		'		'
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Derivative Asset, Fair Value, Amount Offset Against Collateral	32	[1]	'		32	[1]	'		32	[1]
Derivative Asset, Fair Value, Gross Liability	-6		'		-6		'		-8
Net Amount Presented in the Consolidated Balance Sheets (2)	26	[2]	'		26	[2]	'		24	[2]
Natural Gas Derivatives [Member] | Other Assets [Member]	'		'		'		'		'
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Derivative Asset, Fair Value, Amount Offset Against Collateral	14	[1]	'		14	[1]	'		11	[1]
Derivative Asset, Fair Value, Gross Liability	-2		'		-2		'		-1
Net Amount Presented in the Consolidated Balance Sheets (2)	12	[2]	'		12	[2]	'		10	[2]
Natural Gas Derivatives [Member] | Current Liabilities [Member]	'		'		'		'		'
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Derivative Liability, Fair Value, Amount Offset Against Collateral	-18	[1]	'		-18	[1]	'		-25	[1]
Derivative Liability, Fair Value, Gross Asset	6		'		6		'		8
Net Amount Presented in the Consolidated Balance Sheets (2)	-12	[2]	'		-12	[2]	'		-17	[2]
Natural Gas Derivatives [Member] | Other Liabilities [Member]	'		'		'		'		'
Derivative, Fair Value, Net [Abstract]	'		'		'		'		'
Derivative Liability, Fair Value, Amount Offset Against Collateral	-4	[1]	'		-4	[1]	'		-5	[1]
Derivative Liability, Fair Value, Gross Asset	2		'		2		'		1
Net Amount Presented in the Consolidated Balance Sheets (2)	-2	[2]	'		-2	[2]	'		-4	[2]
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	5		27		-96		13		'
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	4	[3]	-18	[3]	114	[3]	-2	[3]	'
Derivative Instruments Physical Forwards Purchased	0		'		2		'		'
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, Gross Asset	31	[4],[5]	'		31	[4],[5]	'		28	[6],[7],[8]
Derivative Liability, Fair Value, Gross Liability	5	[4],[5]	'		5	[4],[5]	'		4	[6],[7],[8]
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, Gross Asset	14	[4],[5]	'		14	[4],[5]	'		10	[6],[8]
Derivative Liability, Fair Value, Gross Liability	2	[4],[5]	'		2	[4],[5]	'		0	[6],[8]
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, Gross Asset	1	[4],[5]	'		1	[4],[5]	'		4	[6],[8]
Derivative Liability, Fair Value, Gross Liability	13	[4],[5]	'		13	[4],[5]	'		21	[6],[8]
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, Gross Asset	0	[4],[5]	'		0	[4],[5]	'		1	[6],[8]
Derivative Liability, Fair Value, Gross Liability	2	[4],[5]	'		2	[4],[5]	'		5	[6],[8]
2012 - 2013 [Member]	'		'		'		'		'
Derivatives, Fair Value [Line Items]	'		'		'		'		'
Weather Hedge, Amount, maximum	'		'		15		'		'
2013 - 2014 [Member]	'		'		'		'		'
Derivatives, Fair Value [Line Items]	'		'		'		'		'
Weather Hedge, Amount, maximum	'		'		$16		'		'
[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 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]	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and six months ended June 30, 2014 related to physical forwards purchased from Enable.
[4]	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $24 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above.
[5]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 603 Bcf or a net 97 Bcf long position. Of the net long position, basis swaps constitute 97 Bcf.
[6]	Natural gas contracts are presented on a net basis in the Condensed Consolidated Balance Sheets. Natural gas contracts 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 derivative assets and liabilities was a $13 million asset as shown on CERC’s Condensed Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of less than $1 million.
[7]	The $28 million Derivative Current Asset includes $1 million related to physical forwards purchased from Enable.
[8]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 607 billion cubic feet (Bcf) or a net 46 Bcf long position. Of the net long position, basis swaps constitute 99 Bcf.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	3 Months Ended				6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
ASSETS	'		'		'		'		'
Corporate equities	$2		'		$2		'		$2
Investments, including money market funds	11		'		11		'		11
Natural gas derivatives	46		'		46		'		43
Natural gas derivatives, assets	38		'		38		'		34	[1]
Total assets	51		'		51		'		47
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives	22		'		22		'		30
Natural gas derivatives, liabilities	14		'		14		'		21
Total liabilities	14		'		14		'		21
Cash collateral posted with counterparties	0		'		0		'		1
Derivative Instruments, Assets, Physical Forwards Purchased	'		'		'		'		1
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation Roll Forward	'		'		'		'		'
Beginning balance	1		3		3		2		'
Total gains	2		1		0		3		'
Total settlements	1		0		2		-1		'
Transfers into Level 3	0		0		-1		0		'
Ending balance (1)	4	[2]	4	[2]	4	[2]	4	[2]	'
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	1		2		2		3		'
Carrying Amount [Member]	'		'		'		'		'
Liabilities [Abstract]	'		'		'		'		'
Notes receivable from unconsolidated affiliates	363		'		363		'		363
Long-term debt	2,125		'		2,125		'		2,240
Fair Value [Member]	'		'		'		'		'
Liabilities [Abstract]	'		'		'		'		'
Notes receivable from unconsolidated affiliates	369		'		369		'		363
Long-term debt	2,466		'		2,466		'		2,466
Fair Value, Inputs, Level 1 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	2		'		2		'		2
Investments, including money market funds	11		'		11		'		11
Natural gas derivatives	3		'		3		'		5	[1]
Total assets	16		'		16		'		18
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives	1		'		1		'		1
Total liabilities	1		'		1		'		1
Fair Value, Inputs, Level 2 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	0		'		0		'		0
Investments, including money market funds	0		'		0		'		0
Natural gas derivatives	37		'		37		'		33	[1]
Total assets	37		'		37		'		33
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives	19		'		19		'		27
Total liabilities	19		'		19		'		27
Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	0		'		0		'		0
Investments, including money market funds	0		'		0		'		0
Natural gas derivatives	6		'		6		'		5	[1]
Total assets	6		'		6		'		5
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives	2		'		2		'		2
Total liabilities	2		'		2		'		2
Netting [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	0	[3]	'		0	[3]	'		0	[4]
Investments, including money market funds	0	[3]	'		0	[3]	'		0	[4]
Natural gas derivatives, netting adjustment	-8	[3]	'		-8	[3]	'		-9	[1],[4]
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives, netting adjustment	($8)	[3]	'		($8)	[3]	'		($9)	[4]
Minimum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Option volatilities	0.00%		'		0.00%		'		'
Maximum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Option volatilities	62.00%		'		62.00%		'		'
Forward Contracts [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Illiquid forward price low range	'		'		2.62		'		'
Forward Contracts [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Illiquid forward price low range	'		'		4.98		'		'
[1]	The (Level 2) Natural gas derivative assets of $33 million includes $1 million related to physical forwards purchased from Enable.
[2]	CERC did not have significant Level 3 purchases, sales or transfers out of Level 3 during the three or six months ended June 30, 2014 or 2013.
[3]	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of $-0- posted with the same counterparties.
[4]	Amounts represent the impact of legally enforceable master netting arrangements that allow CERC to settle positive and negative positions and also include cash collateral of less than $1 million posted with the same counterparties.

Unconsolidated_Affiliates_Deta

Unconsolidated Affiliates (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Apr. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Apr. 16, 2014

Jun. 30, 2014

Apr. 16, 2014

Mar. 31, 2014

Apr. 30, 2014

Jun. 30, 2014

30-May-14

Jun. 30, 2014

30-May-14

Jun. 30, 2014

Jun. 01, 2015

SESH [Member]

SESH [Member]

SESH [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

SESH [Member]

SESH [Member]

SESH [Member]

SESH [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

May 2014 [Member]

Common Stock [Member]

Common Stock [Member]

Subordinated Units [Member]

Scenario, Unspecified [Domain]

CERC Corp [Member]

CERC Corp [Member]

CERC Corp [Member]

ArcLight [Member]

OGE [Member]

SESH [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Common Stock [Member]

Midstream Partnership [Member]

Guarantee of Affiliate Senior Notes

$51,000,000

'

$51,000,000

'

'

'

'

'

$1,100,000,000

'

$1,100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes receivable from unconsolidated affiliates

363,000,000

'

363,000,000

'

363,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

363,000,000

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum

'

'

'

'

'

'

'

'

'

'

2.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum

'

'

'

'

'

'

'

'

'

'

2.45%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Income (Expense), Net

'

'

'

'

'

'

'

'

2,000,000

1,000,000

4,000,000

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Receivable

'

'

'

'

'

'

'

'

5,000,000

'

5,000,000

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transitional Service Costs to be Reimbursed

37,000,000

28,000,000

82,000,000

28,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transitional Services Receivable

20,000,000

'

20,000,000

'

21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Units, Sold in Public Offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,750,000

'

'

'

'

'

'

'

'

3,750,000

'

'

'

'

'

'

Share Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$26.19

'

$26.19

'

$20

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance Initial Public Offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

464,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

50.00%

'

'

'

'

'

Incentive Distribution Right

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

60.00%

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

25.05%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.40%

54.70%

58.30%

'

'

'

'

'

'

'

Equity Method Investment, Additional Contribution of Ownership Percentage

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.95%

'

'

'

'

equity method investment, Additional Contribution of ownership, value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

198,000,000

'

'

'

'

Cost of natural gas purchases, affiliates

27,000,000

28,000,000

75,000,000

28,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to Affiliate, Current

15,000,000

'

15,000,000

'

22,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership, Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

94,126,366

6,322,457

139,704,916

25,341

Investment in unconsolidated affiliates

4,517,000,000

'

4,517,000,000

'

4,518,000,000

0

[1]

'

199,000,000

[1]

4,517,000,000

'

4,517,000,000

'

4,319,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity in earnings of unconsolidated affiliates, net

71,000,000

37,000,000

162,000,000

42,000,000

'

'

'

'

'

'

'

'

'

2,000,000

[2]

4,000,000

[2]

5,000,000

[2]

9,000,000

[2]

'

69,000,000

[3]

33,000,000

[3]

157,000,000

[3]

33,000,000

[3]

'

'

'

'

'

'

'

'

'

'

'

Operating revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

826,000,000

502,000,000

[4]

1,828,000,000

502,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

Cost of sales, excluding depreciation and amortization

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

478,000,000

295,000,000

[4]

1,111,000,000

295,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

Operating income

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

139,000,000

75,000,000

[4]

301,000,000

75,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Enable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

120,000,000

65,000,000

[4]

269,000,000

65,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

CERC's approximate interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

67,000,000

38,000,000

[4]

154,000,000

38,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

Basis difference accretion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Basis Difference Amortization

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-5,000,000

'

-5,000,000

'

'

'

'

'

'

'

'

'

'

'

CERC's equity in earnings, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

69,000,000

33,000,000

157,000,000

33,000,000

'

'

'

'

'

'

'

'

'

'

'

Current assets

'

'

'

'

'

'

'

'

923,000,000

'

923,000,000

'

549,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-current assets

'

'

'

'

'

'

'

'

10,815,000,000

'

10,815,000,000

'

10,683,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current liabilities

'

'

'

'

'

'

'

'

584,000,000

'

584,000,000

'

720,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-current liabilities

'

'

'

'

'

'

'

'

2,343,000,000

'

2,343,000,000

'

2,331,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interest

'

'

'

'

'

'

'

'

32,000,000

'

32,000,000

'

33,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Enable partners' capital

'

'

'

'

'

'

'

'

8,779,000,000

'

8,779,000,000

'

8,148,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CERC's ownership interest in Enable's partner capital

4,862,000,000

'

4,862,000,000

'

4,753,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CERC's basis difference

-345,000,000

'

-345,000,000

'

-434,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CERC's investment in Enable

4,517,000,000

'

4,517,000,000

'

4,319,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions received from Enable

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,000,000

$8,000,000

$7,000,000

$17,000,000

'

$90,000,000

$0

$157,000,000

$0

'

'

'

'

'

'

'

'

'

'

'

[1]

On May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.

[2]

On each of May 1, 2013 and May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.

[3]

On May 1, 2013, CERC formed Enable with OGE and ArcLight.

[4]

The summarized income information for Enable and CERC’s equity in earnings, net of basis difference amortization, presented for the three and six months ended June 30, 2013 reflects Enable’s operating results with the contributions from both OGE and CERC recorded at historical cost for the two-month period from the Closing Date to June 30, 2013.

Goodwill_Goodwill_Details

Goodwill Goodwill (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Goodwill [Line Items]	'	'
Goodwill	$840	$840
Natural Gas Distribution	'	'
Goodwill [Line Items]	'	'
Goodwill	746	746
Energy Services	'	'
Goodwill [Line Items]	'	'
Goodwill	83	83
Other	'	'
Goodwill [Line Items]	'	'
Goodwill	$11	$11

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Investments in Money Pool	$141	'	$141	'	'
Money Pool Borrowings	'	'	'	'	38
Interest Expense Net, Related Party	1	-1	-1	-1	'
Corporate service charges, related party	$31	$23	$59	$60	'

Shortterm_Borrowings_and_Longt2

Short-term Borrowings and Long-term Debt (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Short-term Debt	$42	$43
Line of Credit [Member]	'	'
Line of Credit Facility, Maximum Borrowing Capacity	600	600
Loans Outstanding	0	0
Letters Of Credit Outstanding	0	0
Commercial Paper Outstanding	0	118
Revolving credit facility borrowing rate	'London Interbank Offered Rate plus 150 basis points	'
Percentage on limitation of debt to total capitalization under covenant (in hundredths)	65.00%	'
Product Financing Arrangement [Member]	'	'
Short-term Debt	$42	$43

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	6 Months Ended
	Jun. 30, 2014
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]	'
2014	$259,000,000
2015	528,000,000
2016	454,000,000
2017	384,000,000
2018	376,000,000
After 2018	174,000,000
Loss Contingency Pending Natural Gas Measurement Lawsuits Number	1
Site Contingency Remaining Minnesota Sites	7
Site Contingency Sites Without Liability	2
Site Contingency Completed Remediation	2
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Accrual for Environmental Loss Contingencies	13,000,000
Annual amount included in rates to fund normal on-going remediation costs	285,000
Amount collected from insurance companies to be used for future environmental remediation	6,000,000
Guarantee of Affiliate Senior Notes	51,000,000
Midstream Partnership [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Guarantee of Affiliate Senior Notes	1,100,000,000
Maximum [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Maximum estimated remediation costs for the Minnesota sites	41,000,000
Minimum years of remediation for the Minnesota sites (in years)	'50
Minimum [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Maximum estimated remediation costs for the Minnesota sites	$6,000,000
Minimum years of remediation for the Minnesota sites (in years)	'30

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Effective Income Tax Rate	38.00%	418.00%	38.00%	113.00%
Deferred income taxes	'	'	$116	$289
Midstream Partnership [Member]	'	'	'	'
Deferred Tax Liabilities, Goodwill and Intangible Assets	225	'	225	'
Deferred income taxes	'	'	($27)	'

Reportable_Business_Segments_D

Reportable Business Segments (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

2 Months Ended

3 Months Ended

6 Months Ended

2 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

In Millions, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Energy Services

Energy Services

Energy Services

Energy Services

Energy Services

Interstate Pipelines

Interstate Pipelines

Interstate Pipelines

Field Services

Field Services

Field Services

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Other

Other

Other

Other

Other

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

Midstream Partnership [Member]

SESH [Member]

SESH [Member]

SESH [Member]

SESH [Member]

SESH [Member]

SESH [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Intersegment Eliminations

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Energy Services

Energy Services

Energy Services

Energy Services

Interstate Pipelines

Interstate Pipelines

Field Services

Field Services

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Other

Other

Other

Other

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Additional Contribution of Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

$1,183

$1,235

$3,714

$3,088

'

$526

$524

$2,004

$1,567

'

$657

$622

$1,709

$1,210

'

$41

[1]

$133

[1]

'

$48

[1]

$178

[1]

'

$0

[2]

$0

[2]

$0

[2]

$0

[2]

'

$0

$0

$1

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($25)

($31)

($66)

($99)

($6)

($5)

($15)

($13)

($19)

($6)

($51)

($15)

($13)

[1]

($53)

[1]

($7)

[1]

($18)

[1]

$0

[2]

$0

[2]

$0

[2]

$0

[2]

$0

$0

$0

$0

Operating Income (Loss)

39

56

227

306

'

30

25

192

164

'

11

3

37

10

'

20

[1]

72

[1]

'

20

[1]

73

[1]

'

0

[2]

0

[2]

0

[2]

0

[2]

'

-2

-12

-2

-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets

10,530

'

10,530

'

10,542

4,989

'

4,989

'

4,976

896

'

896

'

895

'

'

0

[1]

'

'

0

[1]

4,517

[2]

'

4,517

[2]

'

4,518

[2]

889

'

889

'

1,149

'

'

'

'

'

'

'

'

'

'

'

'

-761

-996

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity in earnings of unconsolidated affiliates, net

71

37

162

42

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33

69

157

'

'

'

2

2

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment in unconsolidated affiliates

$4,517

'

$4,517

'

$4,518

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,517

$4,319

$4,517

$4,517

$4,517

$4,319

$0

[3]

$199

[3]

$0

$0

$0

$199

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Results reflected in the three months ended June 30, 2013 represent only the month of April 2013. Results reflected in the six months ended June 30, 2013 represent only January 2013 through April 2013.

[2]

Midstream Investments reported equity earnings of $69 million from Enable and $2 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the three months ended June 30, 2014. Midstream Investments reported equity earnings of $157 million from Enable and $5 million of equity earnings from CenterPoint Energy’s retained interest in SESH for the six months ended June 30, 2014. Midstream Investments reported equity earnings of $33 million from Enable and $2 million of equity earnings from CenterPoint Energy’s interest in SESH for the months of May and June 2013. Included in total assets of Midstream Investments as of June 30, 2014 and December 31, 2013 is $4,517 million and $4,319 million, respectively, related to CenterPoint Energy’s investment in Enable and $-0- and $199 million, respectively, related to CenterPoint Energy’s interest in SESH.

[3]

On May 30, 2014, CERC contributed a 24.95% interest in SESH to Enable, leaving CERC with a 0.1% interest in SESH as of June 30, 2014.

Other_Current_Assets_and_Liabi1

Other Current Assets and Liabilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Margin Deposits	$6	$4
Under Recovered Gas Costs	71	22
Over Recovered Gas Costs	$62	$42