Centerpoint Energy Resources 10-Q 10 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document (USD $)	9 Months Ended
	Sep. 30, 2014	Oct. 22, 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-Sep-14	'	'
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'Q3	'	'
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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues	$964	$891	$4,678	$3,979
Expenses:	'	'	'	'
Natural gas	702	637	3,625	2,741
Operation and maintenance	184	172	562	632
Depreciation and amortization	53	49	153	182
Taxes other than income taxes	28	29	114	114
Total	967	887	4,454	3,669
Operating Income (Loss)	-3	4	224	310
Other Income (Expense):	'	'	'	'
Interest and other finance charges	-36	-36	-105	-118
Equity in earnings of unconsolidated affiliates, net	79	80	241	122
Other, net	3	2	7	-3
Total	46	46	143	1
Income Before Income Taxes	43	50	367	311
Income tax expense	15	18	139	313
Net Income (Loss)	$28	$32	$228	($2)

CONDENSED_STATEMENTS_OF_CONSOL1

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net income (loss)	$28	$32	$228	($2)
Adjustment to pension and other postretirement plans (net of tax)	0	0	0	0
Other comprehensive income	0	0	0	0
Comprehensive income (loss)	$28	$32	$228	($2)

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$4	$1
Accounts receivable, less bad debt reserve of $19 and $25, respectively	345	565
Accrued unbilled revenue	74	311
Accounts and notes receivable — affiliated companies	107	44
Materials and supplies	42	34
Natural gas inventory	253	145
Non-trading derivative assets	34	24
Taxes receivable	0	18
Deferred income tax assets	0	21
Prepaid expenses and other current assets	99	51
Total current assets	958	1,214
Property, Plant and Equipment:	'	'
Property, plant and equipment	5,193	4,815
Less: accumulated depreciation and amortization	1,500	1,379
Property, plant and equipment, net	3,693	3,436
Other Assets:	'	'
Goodwill	840	840
Non-trading derivative assets	17	10
Investment in unconsolidated affiliates	4,525	4,518
Notes receivable from unconsolidated affiliates	363	363
Other	149	161
Total other assets	5,894	5,892
Total Assets	10,545	10,542
Current Liabilities:	'	'
Short-term borrowings	80	43
Accounts payable	279	495
Accounts and notes payable — affiliated companies	52	103
Taxes accrued	55	74
Interest accrued	40	36
Customer deposits	77	78
Derivative Liability, Current	11	17
Other	154	163
Total current liabilities	748	1,009
Other Liabilities:	'	'
Deferred Tax Liabilities, Net, Noncurrent	2,189	2,082
Non-trading derivative liabilities	2	4
Benefit obligations	103	102
Regulatory liabilities	692	642
Other	152	160
Total other liabilities	3,138	2,990
Long-Term Debt	2,127	2,240
Commitments and Contingencies (Note 10)	'	'
Stockholder’s Equity:	'	'
Common stock	0	0
Paid-in capital	2,417	2,416
Retained earnings	2,110	1,882
Accumulated other comprehensive income	5	5
Total stockholder’s equity	4,532	4,303
Total Liabilities and Stockholder’s Equity	$10,545	$10,542

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS Balance Sheets Parenthetical (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Allowance for Doubtful Accounts Receivable, Current	$19	$25

CONDENSED_STATEMENTS_OF_CONSOL2

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Cash Flows from Operating Activities:	'	'
Net income (loss)	$228	($2)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation and amortization	153	182
Amortization of deferred financing costs	7	8
Deferred income taxes	132	307
Write-down of natural gas inventory	2	4
Equity in earnings of unconsolidated affiliates, net of distributions	-6	-65
Changes in other assets and liabilities:	'	'
Accounts receivable and unbilled revenues, net	444	255
Accounts receivable/payable - affiliated companies	7	-6
Inventory	-118	-103
Taxes receivable	18	-8
Accounts payable	-220	-152
Fuel cost recovery	-57	105
Interest and taxes accrued	-15	2
Non-trading derivatives, net	-25	-6
Margin deposits, net	-13	5
Other current assets	18	19
Other current liabilities	-8	-20
Other assets	8	-11
Other liabilities	22	17
Other, net	5	3
Net cash provided by operating activities	582	534
Cash Flows from Investing Activities:	'	'
Capital expenditures	-376	-371
Increase in notes receivable - affiliated companies	-83	0
Cash contribution to Enable	0	-38
Other, net	-2	1
Net cash used in investing activities	-461	-408
Cash Flows from Financing Activities:	'	'
Increase in short-term borrowings, net	37	32
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	-679
Other, net	1	-1
Net cash used in financing activities	-118	-123
Net Increase in Cash and Cash Equivalents	3	3
Cash and Cash Equivalents at Beginning of Period	1	1
Cash and Cash Equivalents at End of Period	4	4
Cash Payments:	'	'
Interest, net of capitalized interest	91	113
Income taxes (refunds), net	-1	1
Non-cash transactions:	'	'
Accounts payable related to capital expenditures	25	28
Formation of Enable	0	'
Exercise of SESH put to Enable	'	0
Formation of Enable [Member]	'	'
Non-cash transactions:	'	'
Formation of Enable	'	4,252
Exercise of SESH put to Enable [Member]	'	'
Non-cash transactions:	'	'
Exercise of SESH put to Enable	$196	'

Background_and_Basis_of_Presen

Background and Basis of Presentation	9 Months Ended
	Sep. 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 September 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	9 Months Ended
	Sep. 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	9 Months Ended
	Sep. 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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	1		$	1		$	1		$	1
	Interest cost on accumulated benefit obligation	1			2			4			4
	Expected return on plan assets	(1		)	(1		)	(1		)	(1		)
	Amortization of prior service cost	—			—			—			1
	Amortization of loss	1			1			1			2
	Net periodic cost	$	2		$	3		$	5		$	7
	CERC expects to contribute approximately $7 million to its postretirement benefit plan in 2014, of which $2 million and $5 million was contributed during the three and nine months ended September 30, 2014, respectively.

Derivative_Instruments

Derivative Instruments	9 Months Ended
	Sep. 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 Condensed 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, $16 million in 2013 - 2014 and $16 million in 2014 - 2015.  The swaps are based on ten-year normal weather. During both the three months ended September 30, 2014 and 2013, CERC recognized losses of $-0- related to these swaps. During the nine months ended September 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 September 30, 2014 and December 31, 2013, while the last two tables provide a breakdown of the related income statement impacts for the three and nine months ended September 30, 2014 and 2013.
	Fair Value of Derivative Instruments
					September 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		$	45			$	11
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		17				—
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		1				12
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		3				5
	Total				$	66			$	28
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 811 billion cubic feet (Bcf) or a net 34 Bcf long position.  Of the net long position, basis swaps constitute 126 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 $38 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
			September 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		$	46			$	(12	)		$	34
	Other Assets: Non-trading derivative assets		20				(3		)		17
	Current Liabilities: Non-trading derivative liabilities		(23		)		12				(11		)
	Other Liabilities: Non-trading derivative liabilities		(5		)		3				(2		)
	Total		$	38			$	—			$	38
	________________
	-1	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.
	-2	The derivative assets and liabilities on the Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.
	Fair Value of Derivative Instruments
					December 31, 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 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 September 30,
Total derivatives not designated		Income Statement Location		2014				2013
as hedging instruments
				(in millions)
Natural gas derivatives		Gains (Losses) in Revenue		$	22			$	11
Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		(4		)		(2		)
Total				$	18			$	9
Income Statement Impact of Derivative Activity
				Nine Months Ended September 30,
Total derivatives not designated		Income Statement Location		2014				2013
as hedging instruments
				(in millions)
Natural gas derivatives		Gains (Losses) in Revenue		$	(74	)		$	24
Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		110				(3		)
Total				$	36			$	21
________________
-1	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and nine months ended September 30, 2014, respectively, 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 September 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 September 30, 2014 and December 31, 2013.  If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered at both September 30, 2014 and December 31, 2013, $1 million of additional assets would be required to be posted as collateral.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 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 $2.04 to $4.95 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 81%) 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 nine months ended September 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 September 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 September 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	4			51			11			(15		)	51
	Total assets	$	17		$	51		$	11		$	(15	)	$	64
	Liabilities
	Natural gas derivatives	$	3		$	23		$	2		$	(15	)	$	13
	Total liabilities	$	3		$	23		$	2		$	(15	)	$	13
	________________
	-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 include $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 September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
		(in millions)
	Beginning balance	$	4		$	4		$	3		$	2
	Total gains	6			2			6			5
	Total settlements	(1		)	(1		)	1			(2		)
	Transfers into Level 3	—			—			(1		)	—
	Ending balance (1)	$	9		$	5		$	9		$	5
	The amount of total gains for the period included	$	6		$	2		$	7		$	4
	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 either the three or nine months ended September 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.
		September 30, 2014						December 31, 2013
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
		(in millions)
	Financial assets:
Notes receivable from unconsolidated affiliates	$	363		$	366		$	363		$	363
Financial liabilities:
Long-term debt	$	2,127		$	2,442		$	2,240		$	2,466

Unconsolidated_Affiliates_Note

Unconsolidated Affiliates (Notes)	9 Months Ended
	Sep. 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 basis 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 September 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. 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 $2 million during the three months ended September 30, 2014 and 2013, respectively, and $6 million and $3 million during the nine months ended September 30, 2014 and 2013, respectively, for interest earned on or after the Closing Date and had interest receivable from Enable of $2 million and $4 million as of September 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, $36 million and $42 million during the three months ended September 30, 2014 and 2013, respectively, and $118 million and $70 million during the nine months ended September 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 $17 million and $21 million as of September 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 September 30, 2014. As of September 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 certain severance and termination costs related to the termination of CERC's seconded employees.
	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 $196 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 $24 million and $42 million, during the three months ended September 30, 2014 and 2013, respectively, and $99 million and $70 million during the nine months ended September 30, 2014 and 2013, respectively, for transactions with Enable occurring on or after the Closing Date. CERC had accounts payable to Enable of $10 million and $22 million at September 30, 2014 and December 31, 2013, respectively, from such transactions.
	As of September 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 September 30, 2014, Enable’s common units closed at $24.64 per unit on the New York Stock Exchange.
	Investment in Unconsolidated Affiliates:
			September 30, 2014			December 31, 2013
			(in millions)
	Enable		$	4,524		$	4,319
	SESH (1)		1			199
	Total		$	4,525		$	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 September 30, 2014.
	Equity in Earnings of Unconsolidated Affiliates, net:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	79		$	77		$	236	$	110
	SESH (2)		—			3			5		12
			$	79		$	80		$	241	$	122
	-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 September 30, 2014.
	Summarized unaudited consolidated income information for Enable is as follows:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013 (1)			2014		2013 (1)
			(in millions)
	Operating revenues		$	804		$	796		$	2,632	$	1,298
	Cost of sales, excluding depreciation and amortization		439			458			1,550		753
	Operating income		151			132			452		207
	Net income attributable to Enable		139			123			408		188
	CERC's approximate interest		$	76		$	72		$	230	$	110
	Basis difference accretion		3			5			6		—
	CERC's equity in earnings, net		$	79		$	77		$	236	$	110
	-1	On May 1, 2013, CERC formed Enable with OGE and ArcLight. The amounts included in the table represent the three- and five- month periods ended September 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 its related depreciation and amortization for the five-month period ended September 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 third 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:
			September 30, 2014			December 31, 2013
			(in millions)
	Current assets		$	520		$	549
	Non-current assets		11,172			10,683
	Current liabilities		520			720
	Non-current liabilities		2,346			2,331
	Non-controlling interest		32			33
	Enable partners' capital		8,794			8,148
	CERC's ownership interest in Enable's partner capital		$	4,870		$	4,753
	CERC's basis difference		(346		)	(434		)
	CERC's investment in Enable		$	4,524		$	4,319
	Distributions Received from Unconsolidated Affiliates:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	70		$	36		$	227	$	36
	SESH (2)		1			3			8		21
	Total		$	71		$	39		$	235	$	57
	-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 September 30, 2014.

Goodwill

Goodwill	9 Months Ended
	Sep. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets Disclosure [Text Block]	'
	Goodwill
	Goodwill by reportable business segment as of both September 30, 2014 and December 31, 2013 is as follows (in millions):
	Natural Gas Distribution	$	746
	Energy Services	83
	Other Operations	11
	Total	$	840
	CERC performs its goodwill impairment tests at least annually and evaluates goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. The impairment evaluation for goodwill is performed by using a two-step process. In the first step, the fair value of each reporting unit is compared with the carrying amount of the reporting unit, including goodwill. The estimated fair value of the reporting unit is generally determined on the basis of discounted cash flows. If the estimated fair value of the reporting unit is less than the carrying amount of the reporting unit, then a second step must be completed in order to determine the amount of the goodwill impairment that should be recorded. In the second step, the implied fair value of the reporting unit's goodwill is determined by allocating the reporting unit's fair value to all of its assets and liabilities other than goodwill (including any unrecognized intangible assets) in a manner similar to a purchase price allocation. The resulting implied fair value of the goodwill that results from the application of this second step is then compared to the carrying amount of the goodwill and an impairment charge is recorded for the difference.
	CERC performed its annual impairment test in the third quarter of 2014 and determined, based on the results of the first step, that no impairment charge was required for any reportable segment.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 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 $83 million and borrowings from the money pool of $38 million at September 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 affiliate related net interest income of less than $1 million for both the three and nine months ended September 30, 2014, and net interest expense of less than $1 million and $2 million for the three and nine months ended September 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 $34 million and $28 million for the three months ended September 30, 2014 and 2013, respectively, and $93 million and $88 million for the nine months ended September 30, 2014 and 2013, respectively, and are included primarily in operation and maintenance expenses.
	See Note 6 for related party transactions with Enable.

Shortterm_Borrowings_and_Longt

Short-term Borrowings and Long-term Debt

9 Months Ended

Sep. 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 March 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 $80 million and $43 million as of September 30, 2014 and December 31, 2013, respectively.

(b)

Long-term Debt

Revolving Credit Facility.  On September 9, 2014, CERC Corp's revolving credit facility was amended to, among other things, extend the maturity date of the commitment from September 9, 2018 to September 9, 2019. The amendment also reduced the swingline and letter of credit sub-facility, with the total commitment remaining unchanged.  As of September 30, 2014 and December 31, 2013, CERC had the following revolving credit facility and utilization of such facility (in millions):

September 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, 2019, can be drawn at the London Interbank Offered Rate plus 1.50% 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 September 30, 2014.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 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 September 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 September 30, 2014, minimum payment obligations for natural gas supply commitments are approximately $232 million for the remaining three months in 2014, $634 million in 2015, $557 million in 2016, $485 million in 2017, $434 million in 2018 and $180 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 July 1, 2014. The defendants filed an opening brief with the court on September 18, 2014. The plaintiffs’ brief is due on November 21, 2014, and the other defendants' reply brief is due on December 22, 2014. Four amicus briefs favorable to our co-defendants were filed by the United States, Interstate Natural Gas Association of America, et. al., Washington Legal Foundation and Noble America Corporation, et. al. 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 September 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 September 30, 2014, CERC had collected $6.5 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 $46 million as of September 30, 2014.  Based on market conditions in the fourth quarter of 2014 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.
	The fair value of these guarantees is not material.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The effective tax rate reported for the three and nine months ended September 30, 2014 was 35% and 38%, respectively, compared to 36% and 101%, respectively, for the same periods in 2013. The higher effective tax rate for the nine months ended September 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 September 30, 2014 and expects no significant change to the uncertain tax liability over the next twelve months. CenterPoint Energy’s consolidated federal income tax returns for the years 2012 and 2013 are currently under audit by the Internal Revenue Service (IRS). Tax years through 2011 have been audited and settled with the IRS. For 2014, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

Reportable_Business_Segments

Reportable Business Segments	9 Months Ended
	Sep. 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 September 30, 2014
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	375	$	7		$	(8	)
	Energy Services	589		15			6
	Midstream Investments (1)	—		—			—
	Other	—		—			(1		)
	Reconciling Eliminations	—		(22		)	—
	Consolidated	$	964	$	—		$	(3	)
		For the Three Months Ended September 30, 2013
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	375	$	6		$	5
	Energy Services	516		4			2
	Midstream Investments (1)	—		—			—
	Other	—		—			(3		)
	Reconciling Eliminations	—		(10		)	—
	Consolidated	$	891	$	—		$	4
		For the Nine Months Ended September 30, 2014
		Revenues from		Inter-segment			Operating			Total Assets as of September 30, 2014
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	2,379	$	22		$	184		$	5,059
	Energy Services	2,298		66			43			882
	Midstream Investments (1)	—		—			—			4,525
	Other	1		—			(3		)	769
	Reconciling Eliminations	—		(88		)	—			(690		)
	Consolidated	$	4,678	$	—		$	224		$	10,545
		For the Nine Months Ended September 30, 2013
		Revenues from		Inter-segment			Operating			Total Assets as of December 31, 2013
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	1,942	$	19		$	169		$	4,976
	Energy Services	1,726		19			12			895
	Interstate Pipelines (2)	133		53			72			—
	Field Services (2)	178		18			73			—
	Midstream Investments (1)	—		—			—			4,518
	Other	—		—			(16		)	1,149
	Reconciling Eliminations	—		(109		)	—			(996		)
	Consolidated	$	3,979	$	—		$	310		$	10,542
	-1	Midstream Investments reported equity earnings of $79 million from Enable and less than $1 million of equity earnings from CERC’s retained interest in SESH for the three months ended September 30, 2014. Midstream Investments reported equity earnings of $236 million from Enable and $5 million of equity earnings from CERC’s retained interest in SESH for the nine months ended September 30, 2014. Midstream Investments reported equity earnings of $77 million from Enable and $3 million of equity earnings from CERC’s interest in SESH for the three months ended September 30, 2013. Midstream Investments reported equity earnings of $110 million from Enable and $5 million of equity earnings from CERC’s interest in SESH for the five months ended September 30, 2013. Included in total assets of Midstream Investments as of September 30, 2014 and December 31, 2013 is $4,524 million and $4,319 million, respectively, related to CERC’s investment in Enable and $1 million and $199 million, respectively, related to CERC’s interest in SESH.
	-2	Results reflected in the nine months ended September 30, 2013 represent only January 2013 through April 2013.

Other_Current_Assets_and_Liabi

Other Current Assets and Liabilities	9 Months Ended
	Sep. 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 September 30, 2014 and December 31, 2013 were $18 million and $4 million, respectively, of margin deposits and $70 million and $22 million, respectively, of under-recovered gas cost. Included in other current liabilities on the Condensed Consolidated Balance Sheets at September 30, 2014 and December 31, 2013 were $47 million and $42 million, respectively, of over-recovered gas cost.

Employee_Benefit_Plans_Employe1

Employee Benefit Plans Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	1		$	1		$	1		$	1
	Interest cost on accumulated benefit obligation	1			2			4			4
	Expected return on plan assets	(1		)	(1		)	(1		)	(1		)
	Amortization of prior service cost	—			—			—			1
	Amortization of loss	1			1			1			2
	Net periodic cost	$	2		$	3		$	5		$	7

Derivative_Instruments_Derivat

Derivative Instruments Derivative Instruments (Tables)	9 Months Ended
	Sep. 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 September 30, 2014 and December 31, 2013, while the last two tables provide a breakdown of the related income statement impacts for the three and nine months ended September 30, 2014 and 2013.
	Fair Value of Derivative Instruments
					September 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		$	45			$	11
	Natural gas derivatives (1) (2)		Other Assets: Non-trading derivative assets		17				—
	Natural gas derivatives (1) (2)		Current Liabilities: Non-trading derivative liabilities		1				12
	Natural gas derivatives (1) (2)		Other Liabilities: Non-trading derivative liabilities		3				5
	Total				$	66			$	28
	________________
	-1	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 811 billion cubic feet (Bcf) or a net 34 Bcf long position.  Of the net long position, basis swaps constitute 126 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 $38 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
			September 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		$	46			$	(12	)		$	34
	Other Assets: Non-trading derivative assets		20				(3		)		17
	Current Liabilities: Non-trading derivative liabilities		(23		)		12				(11		)
	Other Liabilities: Non-trading derivative liabilities		(5		)		3				(2		)
	Total		$	38			$	—			$	38
	________________
	-1	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.
	-2	The derivative assets and liabilities on the Condensed Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.
	Fair Value of Derivative Instruments
					December 31, 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 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 September 30,
	Total derivatives not designated		Income Statement Location		2014				2013
	as hedging instruments
					(in millions)
	Natural gas derivatives		Gains (Losses) in Revenue		$	22			$	11
	Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		(4		)		(2		)
	Total				$	18			$	9
	Income Statement Impact of Derivative Activity
					Nine Months Ended September 30,
	Total derivatives not designated		Income Statement Location		2014				2013
	as hedging instruments
					(in millions)
	Natural gas derivatives		Gains (Losses) in Revenue		$	(74	)		$	24
	Natural gas derivatives (1)		Gains (Losses) in Expense: Natural Gas		110				(3		)
	Total				$	36			$	21
	________________
	-1	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and nine months ended September 30, 2014, respectively, related to physical forwards purchased from Enable.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 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 September 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 September 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	4			51			11			(15		)	51
	Total assets	$	17		$	51		$	11		$	(15	)	$	64
	Liabilities
	Natural gas derivatives	$	3		$	23		$	2		$	(15	)	$	13
	Total liabilities	$	3		$	23		$	2		$	(15	)	$	13
	________________
	-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 include $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 September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
		(in millions)
	Beginning balance	$	4		$	4		$	3		$	2
	Total gains	6			2			6			5
	Total settlements	(1		)	(1		)	1			(2		)
	Transfers into Level 3	—			—			(1		)	—
	Ending balance (1)	$	9		$	5		$	9		$	5
	The amount of total gains for the period included	$	6		$	2		$	7		$	4
	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 either the three or nine months ended September 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.
		September 30, 2014						December 31, 2013
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
		(in millions)
	Financial assets:
	Notes receivable from unconsolidated affiliates	$	363		$	366		$	363		$	363
	Financial liabilities:
	Long-term debt	$	2,127		$	2,442		$	2,240		$	2,466

Unconsolidated_Affiliates_Tabl

Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments [Table Text Block]	'
	Investment in Unconsolidated Affiliates:
			September 30, 2014			December 31, 2013
			(in millions)
	Enable		$	4,524		$	4,319
	SESH (1)		1			199
	Total		$	4,525		$	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 September 30, 2014.
	Equity in Earnings of Unconsolidated Affiliates, net:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	79		$	77		$	236	$	110
	SESH (2)		—			3			5		12
			$	79		$	80		$	241	$	122
	-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 September 30, 2014.
	Summarized unaudited consolidated income information for Enable is as follows:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013 (1)			2014		2013 (1)
			(in millions)
	Operating revenues		$	804		$	796		$	2,632	$	1,298
	Cost of sales, excluding depreciation and amortization		439			458			1,550		753
	Operating income		151			132			452		207
	Net income attributable to Enable		139			123			408		188
	CERC's approximate interest		$	76		$	72		$	230	$	110
	Basis difference accretion		3			5			6		—
	CERC's equity in earnings, net		$	79		$	77		$	236	$	110
	-1	On May 1, 2013, CERC formed Enable with OGE and ArcLight. The amounts included in the table represent the three- and five- month periods ended September 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 its related depreciation and amortization for the five-month period ended September 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 third 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:
			September 30, 2014			December 31, 2013
			(in millions)
	Current assets		$	520		$	549
	Non-current assets		11,172			10,683
	Current liabilities		520			720
	Non-current liabilities		2,346			2,331
	Non-controlling interest		32			33
	Enable partners' capital		8,794			8,148
	CERC's ownership interest in Enable's partner capital		$	4,870		$	4,753
	CERC's basis difference		(346		)	(434		)
	CERC's investment in Enable		$	4,524		$	4,319
	Distributions Received from Unconsolidated Affiliates:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2014			2013			2014		2013
			(in millions)
	Enable (1)		$	70		$	36		$	227	$	36
	SESH (2)		1			3			8		21
	Total		$	71		$	39		$	235	$	57
	-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 September 30, 2014.

Goodwill_Goodwill_Tables

Goodwill Goodwill (Tables)	9 Months Ended
	Sep. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill [Table Text Block]	'
	Goodwill by reportable business segment as of both September 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)

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

'

Schedule of Line of Credit Facilities [Table Text Block]

'

Revolving Credit Facility.  On September 9, 2014, CERC Corp's revolving credit facility was amended to, among other things, extend the maturity date of the commitment from September 9, 2018 to September 9, 2019. The amendment also reduced the swingline and letter of credit sub-facility, with the total commitment remaining unchanged.  As of September 30, 2014 and December 31, 2013, CERC had the following revolving credit facility and utilization of such facility (in millions):

September 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)	9 Months Ended
	Sep. 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 September 30, 2014
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	375	$	7		$	(8	)
	Energy Services	589		15			6
	Midstream Investments (1)	—		—			—
	Other	—		—			(1		)
	Reconciling Eliminations	—		(22		)	—
	Consolidated	$	964	$	—		$	(3	)
		For the Three Months Ended September 30, 2013
		Revenues from		Inter-segment			Operating
		External		Revenues			Income
		Customers					(Loss)
	Natural Gas Distribution	$	375	$	6		$	5
	Energy Services	516		4			2
	Midstream Investments (1)	—		—			—
	Other	—		—			(3		)
	Reconciling Eliminations	—		(10		)	—
	Consolidated	$	891	$	—		$	4
		For the Nine Months Ended September 30, 2014
		Revenues from		Inter-segment			Operating			Total Assets as of September 30, 2014
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	2,379	$	22		$	184		$	5,059
	Energy Services	2,298		66			43			882
	Midstream Investments (1)	—		—			—			4,525
	Other	1		—			(3		)	769
	Reconciling Eliminations	—		(88		)	—			(690		)
	Consolidated	$	4,678	$	—		$	224		$	10,545
		For the Nine Months Ended September 30, 2013
		Revenues from		Inter-segment			Operating			Total Assets as of December 31, 2013
		External		Revenues			Income (Loss)
		Customers
	Natural Gas Distribution	$	1,942	$	19		$	169		$	4,976
	Energy Services	1,726		19			12			895
	Interstate Pipelines (2)	133		53			72			—
	Field Services (2)	178		18			73			—
	Midstream Investments (1)	—		—			—			4,518
	Other	—		—			(16		)	1,149
	Reconciling Eliminations	—		(109		)	—			(996		)
	Consolidated	$	3,979	$	—		$	310		$	10,542
	-1	Midstream Investments reported equity earnings of $79 million from Enable and less than $1 million of equity earnings from CERC’s retained interest in SESH for the three months ended September 30, 2014. Midstream Investments reported equity earnings of $236 million from Enable and $5 million of equity earnings from CERC’s retained interest in SESH for the nine months ended September 30, 2014. Midstream Investments reported equity earnings of $77 million from Enable and $3 million of equity earnings from CERC’s interest in SESH for the three months ended September 30, 2013. Midstream Investments reported equity earnings of $110 million from Enable and $5 million of equity earnings from CERC’s interest in SESH for the five months ended September 30, 2013. Included in total assets of Midstream Investments as of September 30, 2014 and December 31, 2013 is $4,524 million and $4,319 million, respectively, related to CERC’s investment in Enable and $1 million and $199 million, respectively, related to CERC’s interest in SESH.
	-2	Results reflected in the nine months ended September 30, 2013 represent only January 2013 through April 2013.

Background_and_Basis_of_Presen1

Background and Basis of Presentation (Details) (Enable Midstream Partners [Member])	Sep. 30, 2014	Apr. 16, 2014	Mar. 31, 2014
Enable Midstream Partners [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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Other Postretirement Benefit Plans, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Service cost	$1	$1	$1	$1
Interest cost on accumulated benefit obligation	1	2	4	4
Expected return on plan assets	-1	-1	-1	-1
Amortization of prior service cost	0	0	0	1
Amortization of loss	1	1	1	2
Net periodic cost	2	3	5	7
Contribution expected in 2013	'	'	7	'
Contribution made in period	$2	'	$5	'

Derivative_Instruments_Derivat1

Derivative Instruments Derivatives and Hedging (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Term of normal weather used as the basis for weather hedges (in years)	'	'	'10	'
2012 - 2013 [Member]	'	'	'	'
Weather Hedge, Amount, maximum	'	'	$15	'
2013 - 2014 [Member]	'	'	'	'
Weather Hedge, Amount, maximum	'	'	16	'
2014 - 2015 [Member]	'	'	'	'
Weather Hedge, Amount, maximum	16	'	'	'
Weather Hedge Swaps [Member] | Sales [Member]	'	'	'	'
Gains (Losses) Recognized Related to Weather Hedges	$0	$0	($7)	($6)

Derivative_Instruments_Derivat2

Derivative Instruments Derivative Instruments (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Long [Member]

Long [Member]

Swap [Member]

Swap [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

MMcf

MMcf

Current Assets [Member]

Current Assets [Member]

Other Noncurrent Assets [Member]

Other Noncurrent Assets [Member]

Current Liabilities [Member]

Current Liabilities [Member]

Other Noncurrent Liabilities [Member]

Other Noncurrent Liabilities [Member]

Gains (Losses) in Revenue

Gains (Losses) in Revenue

Gains (Losses) in Revenue

Gains (Losses) in Revenue

Gains (Losses) in Expense: Natural Gas [Member]

Gains (Losses) in Expense: Natural Gas [Member]

Gains (Losses) in Expense: Natural Gas [Member]

Gains (Losses) in Expense: Natural Gas [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Long [Member]

Long [Member]

Forward Contracts [Member]

Forward Contracts [Member]

Forward Contracts [Member]

Forward Contracts [Member]

Current Assets [Member]

Current Assets [Member]

Other Assets [Member]

Other Noncurrent Assets [Member]

Current Liabilities [Member]

Current Liabilities [Member]

Other Noncurrent Liabilities [Member]

Other Liabilities [Member]

MMcf

MMcf

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Energy Related Derivative [Member]

Not Designated as Hedging Instrument [Member]

MMcf

MMcf

Gains (Losses) in Expense: Natural Gas [Member]

Gains (Losses) in Expense: Natural Gas [Member]

Energy Related Derivative [Member]

Current Assets [Member]

Derivatives, Fair Value [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement

'

'

'

'

'

'

'

$46

[1]

$32

[1]

$20

[1]

$11

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset

'

'

'

'

'

'

'

-12

-8

-3

-1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Asset

'

'

'

'

'

'

'

34

[2]

24

[2]

17

[2]

10

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement

'

'

'

'

'

'

'

'

'

'

'

-23

[1]

-25

[1]

-5

[1]

-5

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset

'

'

'

'

'

'

'

'

'

'

'

12

8

3

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liability

'

'

'

'

'

'

'

'

'

'

'

-11

[2]

-17

[2]

-2

[2]

-4

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gross Amounts Recognized (1)

'

'

'

'

'

38

[1]

13

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Fair Value, Offsets, Net

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Assets (Liabilities), at Fair Value, Net

'

'

'

'

'

38

[2]

13

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

collateral Netting

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount, Volume

'

'

'

'

'

811,000

607,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

34,000

46,000

126,000

99,000

'

'

'

'

Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Instruments, Assets, Physical Forwards Purchased

66

'

66

'

43

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

45

[3],[4]

28

[5],[6],[7]

17

[3],[4]

10

[6],[7]

1

[3],[4]

4

[6],[7]

1

[6],[7]

3

[3],[4]

'

'

'

'

1

'

'

1

Derivative Liability, Fair Value, Gross Liability

28

'

28

'

30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

[3],[4]

4

[5],[6],[7]

0

[3],[4]

0

[6],[7]

12

[3],[4]

21

[6],[7]

5

[6],[7]

5

[3],[4]

'

'

'

'

'

'

'

'

Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net

18

9

36

21

'

'

'

'

'

'

'

'

'

'

'

22

11

-74

24

-4

[8]

-2

[8]

110

[8]

-3

[8]

'

'

'

'

'

'

'

'

'

'

'

'

'

0

2

'

Derivative, Fair Value, Net [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

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

[2]

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

[3]

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 $38 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.

[4]

The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 811 billion cubic feet (Bcf) or a net 34 Bcf long position. Of the net long position, basis swaps constitute 126 Bcf.

[5]

The $28 million Derivative Current Asset includes $1 million related to physical forwards purchased from Enable.

[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 fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 607 Bcf or a net 46 Bcf long position. Of the net long position, basis swaps constitute 99 Bcf.

[8]

The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the three and nine months ended September 30, 2014, respectively, related to physical forwards purchased from Enable.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013		Dec. 31, 2013
ASSETS	'		'		'		'		'
Natural gas derivatives, netting adjustment	($15,000,000)	[1]	'		($15,000,000)	[1]	'		($9,000,000)	[2]
Total assets	64,000,000		'		64,000,000		'		47,000,000
Liabilities [Abstract]	'		'		'		'		'
Natural gas derivatives, netting adjustment	-15,000,000	[1]	'		-15,000,000	[1]	'		-9,000,000	[2]
Liabilities, Fair Value Disclosure, Recurring	13,000,000		'		13,000,000		'		21,000,000
Cash collateral posted with counterparties	0		'		0		'		1,000,000
Derivative Instruments, Assets, Physical Forwards Purchased	66,000,000		'		66,000,000		'		43,000,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]	'		'		'		'		'
Beginning balance	4,000,000		4,000,000		3,000,000		2,000,000		'
Total gains	6,000,000		2,000,000		6,000,000		5,000,000		'
Total settlements	-1,000,000		-1,000,000		1,000,000		-2,000,000		'
Transfers into Level 3	0		0		-1,000,000		0		'
Ending balance (1)	9,000,000	[3]	5,000,000	[3]	9,000,000	[3]	5,000,000	[3]	'
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	6,000,000		2,000,000		7,000,000		4,000,000		'
Carrying Amount [Member]	'		'		'		'		'
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation Roll Forward	'		'		'		'		'
Notes receivable from unconsolidated affiliates	363,000,000		'		363,000,000		'		363,000,000
Long-term debt	2,127,000,000		'		2,127,000,000		'		2,240,000,000
Fair Value [Member]	'		'		'		'		'
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation Roll Forward	'		'		'		'		'
Notes receivable from unconsolidated affiliates	366,000,000		'		366,000,000		'		363,000,000
Long-term debt	2,442,000,000		'		2,442,000,000		'		2,466,000,000
Fair Value, Inputs, Level 1 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	0		'		0		'		'
Fair Value, Liabilities, Level 1 to Level 2 Transfers, Amount	0		'		0		'		'
ASSETS	'		'		'		'		'
Total assets	17,000,000		'		17,000,000		'		18,000,000
Liabilities [Abstract]	'		'		'		'		'
Liabilities, Fair Value Disclosure, Recurring	3,000,000		'		3,000,000		'		1,000,000
Fair Value, Inputs, Level 2 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value, Assets, Level 2 to Level 1 Transfers, Amount	0		'		0		'		'
Fair Value, Liabilities, Level 2 to Level 1 Transfers, Amount	0		'		0		'		'
ASSETS	'		'		'		'		'
Total assets	51,000,000		'		51,000,000		'		33,000,000
Liabilities [Abstract]	'		'		'		'		'
Liabilities, Fair Value Disclosure, Recurring	23,000,000		'		23,000,000		'		27,000,000
Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Total assets	11,000,000		'		11,000,000		'		5,000,000
Liabilities [Abstract]	'		'		'		'		'
Liabilities, Fair Value Disclosure, Recurring	2,000,000		'		2,000,000		'		2,000,000
Forward Contracts [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value Inputs, Price Per MMBtu	'		'		2.04		'		'
Forward Contracts [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value Inputs, Price Per MMBtu	'		'		4.95		'		'
Options Held [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value Assumptions, Expected Volatility Rate	'		'		0.00%		'		'
Options Held [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'		'		'
Fair Value Assumptions, Expected Volatility Rate	'		'		81.00%		'		'
Fair Value, Measurements, Recurring [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	2,000,000		'		2,000,000		'		2,000,000
Investments, including money market funds	11,000,000		'		11,000,000		'		11,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	2,000,000		'		2,000,000		'		2,000,000
Investments, including money market funds	11,000,000		'		11,000,000		'		11,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	0		'		0		'		0
Investments, including money market funds	0		'		0		'		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Corporate equities	0		'		0		'		0
Investments, including money market funds	0		'		0		'		0
Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	-15,000,000	[1]	'		-15,000,000	[1]	'		-9,000,000	[2],[4]
Derivative Asset	51,000,000		'		51,000,000		'		34,000,000	[4]
Liabilities [Abstract]	'		'		'		'		'
Derivative Liability	13,000,000		'		13,000,000		'		21,000,000
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	-15,000,000	[1]	'		-15,000,000	[1]	'		-9,000,000	[2]
Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member] | Fair Value, Inputs, Level 1 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	4,000,000		'		4,000,000		'		5,000,000	[4]
Liabilities [Abstract]	'		'		'		'		'
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	3,000,000		'		3,000,000		'		1,000,000
Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member] | Fair Value, Inputs, Level 2 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	51,000,000		'		51,000,000		'		33,000,000	[4]
Liabilities [Abstract]	'		'		'		'		'
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	23,000,000		'		23,000,000		'		27,000,000
Fair Value, Measurements, Recurring [Member] | Energy Related Derivative [Member] | Fair Value, Inputs, Level 3 [Member]	'		'		'		'		'
ASSETS	'		'		'		'		'
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	11,000,000		'		11,000,000		'		5,000,000	[4]
Liabilities [Abstract]	'		'		'		'		'
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	2,000,000		'		2,000,000		'		2,000,000
Enable Midstream Partners [Member] | Energy Related Derivative [Member] | Forward Contracts [Member]	'		'		'		'		'
Liabilities [Abstract]	'		'		'		'		'
Derivative Instruments, Assets, Physical Forwards Purchased	'		'		'		'		$1,000,000
[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.
[2]	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.
[3]	CERC did not have significant Level 3 purchases, sales or transfers out of Level 3 during either the three or nine months ended September 30, 2014 or 2013.
[4]	The (Level 2) Natural gas derivative assets of $33 million include $1 million related to physical forwards purchased from Enable.

Unconsolidated_Affiliates_Desc

Unconsolidated Affiliates Description (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Apr. 16, 2014

Sep. 30, 2014

Apr. 16, 2014

Mar. 31, 2014

Apr. 16, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

30-May-14

Sep. 30, 2014

Sep. 30, 2014

30-May-14

Jun. 01, 2015

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

May 2014 [Member]

Subordinated Units [Member]

Common Stock [Member]

Common Stock [Member]

Subsequent Event [Member]

Enable Guaranteed Senior Notes [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Transitional Service [Member]

Transitional Service [Member]

Transitional Service [Member]

Transitional Service [Member]

Transitional Service [Member]

Natural Gas Expenses [Member]

Natural Gas Expenses [Member]

Natural Gas Expenses [Member]

Natural Gas Expenses [Member]

Natural Gas Expenses [Member]

ArcLight [Member]

OGE [Member]

Southeast Supply Header LLC [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Common Stock [Member]

Enable Guaranteed Senior Notes [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Guarantee of Affiliate Senior Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,100,000,000

'

'

'

'

'

$1,100,000,000

'

'

'

'

'

'

'

'

'

'

Due from Affiliate, Noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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, Related Party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

2,000,000

6,000,000

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Accounts and notes receivable — affiliated companies

107,000,000

44,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

2,000,000

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

Reimbursement Revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36,000,000

42,000,000

118,000,000

70,000,000

'

'

'

'

'

'

Accounts Receivable, Related Parties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

17,000,000

'

21,000,000

'

'

'

'

'

Partners' Capital Account, Units, Sold in Public Offering

'

'

28,750,000

'

'

'

3,750,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share Price

'

'

'

$24.64

$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

'

'

'

55.40%

54.70%

58.30%

'

'

0.10%

25.05%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Additional Contribution of Ownership Percentage

'

'

'

'

'

'

'

'

'

'

24.95%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership, Shares

'

'

'

'

'

'

'

'

'

'

'

139,704,916

94,126,366

6,322,457

25,341

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

equity method investment, Additional Contribution of ownership, value

'

'

'

'

'

'

'

'

'

'

196,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Affiliate Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24,000,000

42,000,000

99,000,000

70,000,000

'

Accounts Payable, Related Parties, Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10,000,000

'

$10,000,000

'

$22,000,000

Unconsolidated_Affiliates_Fina

Unconsolidated Affiliates Financial Data(Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Apr. 16, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Dec. 31, 2013

30-May-14

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

May 2014 [Member]

Southeast Supply Header LLC [Member]

Investment in unconsolidated affiliates

$4,525

'

$4,525

'

$4,518

$4,524

'

$4,524

'

'

'

$4,319

$1

[1]

'

$1

[1]

'

'

$199

[1]

'

Equity in earnings of unconsolidated affiliates, net

79

80

241

122

'

79

[2]

77

[2]

236

[2]

110

[2]

'

'

'

0

[3]

3

[3]

5

[3]

12

[3]

'

'

'

Operating revenues

'

'

'

'

'

804

796

[4]

2,632

1,298

[4]

'

'

'

'

'

'

'

'

'

'

Cost of sales, excluding depreciation and amortization

'

'

'

'

'

439

458

[4]

1,550

753

[4]

'

'

'

'

'

'

'

'

'

'

Operating income

'

'

'

'

'

151

132

[4]

452

207

[4]

'

'

'

'

'

'

'

'

'

'

Net income attributable to Enable

'

'

'

'

'

139

123

[4]

408

188

[4]

'

'

'

'

'

'

'

'

'

'

CERC's approximate interest

'

'

'

'

'

76

72

[4]

230

110

[4]

'

'

'

'

'

'

'

'

'

'

Basis difference accretion

'

'

'

'

'

3

5

[4]

6

0

[4]

'

'

'

'

'

'

'

'

'

'

CERC's equity in earnings, net

'

'

'

'

'

79

77

[4]

236

110

[4]

'

'

'

'

'

'

'

'

'

'

Current assets

'

'

'

'

'

520

'

520

'

'

'

549

'

'

'

'

'

'

'

Non-current assets

'

'

'

'

'

11,172

'

11,172

'

'

'

10,683

'

'

'

'

'

'

'

Current liabilities

'

'

'

'

'

520

'

520

'

'

'

720

'

'

'

'

'

'

'

Non-current liabilities

'

'

'

'

'

2,346

'

2,346

'

'

'

2,331

'

'

'

'

'

'

'

Non-controlling interest

'

'

'

'

'

32

'

32

'

'

'

33

'

'

'

'

'

'

'

Enable partners' capital

'

'

'

'

'

8,794

'

8,794

'

'

'

8,148

'

'

'

'

'

'

'

CERC's ownership interest in Enable's partner capital

4,870

'

4,870

'

4,753

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CERC's basis difference

-346

'

-346

'

-434

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CERC's investment in Enable

4,524

'

4,524

'

4,319

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Equity Method Investment, Dividends or Distributions

$71

$39

$235

$57

'

$70

[2]

$36

[2]

$227

[2]

$36

[2]

'

'

'

$1

[3]

$3

[3]

$8

[3]

$21

[3]

'

'

'

Equity Method Investment, Additional Contribution of Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.95%

Equity Method Investment, Ownership Percentage

'

'

'

'

'

55.40%

'

55.40%

'

54.70%

58.30%

'

0.10%

'

0.10%

'

25.05%

'

'

[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 September 30, 2014.

[2]

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

[3]

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 September 30, 2014.

[4]

On May 1, 2013, CERC formed Enable with OGE and ArcLight. The amounts included in the table represent the three- and five- month periods ended September 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 its related depreciation and amortization for the five-month period ended September 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 third quarter of 2013 was not materially different as a result of the final fair value determination.

Goodwill_Goodwill_Details

Goodwill Goodwill (Details) (USD $)	Sep. 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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Investments in Money Pool	$83	'	$83	'	'
Money Pool Borrowings	'	'	'	'	38
Interest Expense Net, Related Party	1	-1	1	-2	'
Corporate service charges, related party	$34	$28	$93	$88	'

Shortterm_Borrowings_and_Longt2

Short-term Borrowings and Long-term Debt (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Short-term Debt	$80	$43
Line of Credit Facility, Maximum Borrowing Capacity	600	600
Product Financing Arrangement [Member]	'	'
Short-term Debt	80	43
Revolving Credit Facility [Member]	'	'
Loans Outstanding	0	0
Percentage on limitation of debt to total capitalization under covenant (in hundredths)	65.00%	'
Letter of Credit [Member]	'	'
Loans Outstanding	0	0
Commercial Paper [Member]	'	'
Loans Outstanding	$0	$118
London Interbank Offered Rate (LIBOR) [Member] | Revolving Credit Facility [Member]	'	'
Debt Instrument, Basis Spread on Variable Rate	1.50%	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	9 Months Ended
	Sep. 30, 2014
Natural Gas Supply Commitments [Member]	'
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]	'
2014	$232,000,000
2015	634,000,000
2016	557,000,000
2017	485,000,000
2018	434,000,000
After 2018	180,000,000
Gas Market Manipulation Cases [Member]	'
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]	'
Loss Contingency Pending Natural Gas Measurement Lawsuits Number	1
Loss Contingency, Amicus Briefs filed, number	4
Minnesota Service Territory [Member]	'
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]	'
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	6,500,000
Minnesota Service Territory [Member] | Maximum [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Site Contingency, Loss Exposure Not Accrued, Low Estimate	41,000,000
Minimum years of remediation for the Minnesota sites (in years)	'50
Minnesota Service Territory [Member] | Minimum [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Site Contingency, Loss Exposure Not Accrued, Low Estimate	6,000,000
Minimum years of remediation for the Minnesota sites (in years)	'30
GenOn Demand Charges Transportation Contracts [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Guarantee of Affiliate Senior Notes	46,000,000
Enable Guaranteed Senior Notes [Member]	'
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract	'
Guarantee of Affiliate Senior Notes	$1,100,000,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Effective Income Tax Rate	35.00%	36.00%	38.00%	101.00%
Tax Effect Related To Formation Of Enable [Member]	'	'	'	'
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Impairment Losses, Amount	'	'	'	225
Effective Income Tax Rate Reconciliation, Prior Year Income Taxes, Amount	'	'	'	27

Reportable_Business_Segments_D

Reportable Business Segments (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

5 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

5 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Apr. 16, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 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

Field Services

Field Services

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Other

Other

Other

Other

Other

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

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Southeast Supply Header LLC [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Enable Midstream Partners [Member]

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Natural Gas Distribution

Energy Services

Energy Services

Energy Services

Energy Services

Interstate Pipelines

Field Services

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Other

Other

Other

Other

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Midstream Investments (1)

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Additional Contribution of Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.10%

'

0.10%

'

25.05%

'

'

'

'

'

'

55.40%

'

55.40%

'

54.70%

58.30%

'

'

'

'

'

'

Revenues

$964

$891

$4,678

$3,979

'

$375

$375

$2,379

$1,942

'

$589

$516

$2,298

$1,726

'

$133

[1]

'

$178

[1]

'

$0

[2]

$0

[2]

$0

[2]

$0

[2]

'

$0

$0

$1

$0

'

'

'

($22)

($10)

($88)

($109)

($7)

($6)

($22)

($19)

($15)

($4)

($66)

($19)

($53)

[1]

($18)

[1]

$0

[2]

$0

[2]

$0

[2]

$0

[2]

$0

$0

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Income (Loss)

-3

4

224

310

'

-8

5

184

169

'

6

2

43

12

'

72

[1]

'

73

[1]

'

0

[2]

0

[2]

0

[2]

0

[2]

'

-1

-3

-3

-16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets

10,545

'

10,545

'

10,542

5,059

'

5,059

'

4,976

882

'

882

'

895

'

0

[1]

'

0

[1]

4,525

[2]

'

4,525

[2]

'

4,518

[2]

769

'

769

'

1,149

-690

-996

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity in earnings of unconsolidated affiliates, net

79

80

241

122

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

[3]

3

[3]

5

[3]

12

[3]

'

'

1

3

5

5

'

79

[4]

77

[4]

236

[4]

110

[4]

'

'

'

79

77

110

236

'

Investment in unconsolidated affiliates

$4,525

'

$4,525

'

$4,518

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1

[5]

'

$1

[5]

'

'

$199

[5]

$1

'

'

$1

$199

$4,524

'

$4,524

'

'

'

$4,319

$4,524

'

'

$4,524

$4,319

[1]

Results reflected in the nine months ended September 30, 2013 represent only January 2013 through April 2013.

[2]

Midstream Investments reported equity earnings of $79 million from Enable and less than $1 million of equity earnings from CERC’s retained interest in SESH for the three months ended September 30, 2014. Midstream Investments reported equity earnings of $236 million from Enable and $5 million of equity earnings from CERC’s retained interest in SESH for the nine months ended September 30, 2014. Midstream Investments reported equity earnings of $77 million from Enable and $3 million of equity earnings from CERC’s interest in SESH for the three months ended September 30, 2013. Midstream Investments reported equity earnings of $110 million from Enable and $5 million of equity earnings from CERC’s interest in SESH for the five months ended September 30, 2013. Included in total assets of Midstream Investments as of September 30, 2014 and December 31, 2013 is $4,524 million and $4,319 million, respectively, related to CERC’s investment in Enable and $1 million and $199 million, respectively, related to CERC’s interest in SESH.

[3]

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 September 30, 2014.

[4]

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

[5]

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 September 30, 2014.

Other_Current_Assets_and_Liabi1

Other Current Assets and Liabilities (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Margin Deposits	$18	$4
Under Recovered Gas Costs	70	22
Over Recovered Gas Costs	$47	$42