View Filing Data

Document and Entity Information Document - USD ($)	6 Months Ended
Document and Entity Information Document - USD ($)	Jun. 30, 2015	Jul. 31, 2015	Jun. 30, 2014
Entity Information [Line Items]
Entity Registrant Name	CENTERPOINT ENERGY RESOURCES CORP
Entity Central Index Key	0001042773
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		1,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

CONDENSED STATEMENTS OF CONSOLIDATED INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Statement [Abstract]
Revenues	$ 824	$ 1,183	$ 2,641	$ 3,714
Expenses:
Natural gas	529	880	1,883	2,923
Operation and maintenance	179	179	376	378
Depreciation and amortization	56	51	112	100
Taxes other than income taxes	33	34	83	86
Total	797	1,144	2,454	3,487
Operating Income	27	39	187	227
Other Income (Expense):
Interest and other finance charges	(35)	(34)	(69)	(69)
Equity in earnings of unconsolidated affiliates, net	43	71	95	162
Other, net	(1)	2	1	4
Total	7	39	27	97
Income Before Income Taxes	34	78	214	324
Income tax expense	12	30	83	124
Net Income	$ 22	$ 48	$ 131	$ 200

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ 22	$ 48	$ 131	$ 200
Other comprehensive income, net of tax:
Adjustment to pension and other postretirement plans (net of tax)	0	0	0	0
Other comprehensive income	0	0	0	0
Comprehensive income	$ 22	$ 48	$ 131	$ 200

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References + Details

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents	$ 1	$ 2
Accounts receivable, less bad debt reserve of $25 and $23, respectively	341	595
Accrued unbilled revenue	70	262
Accounts and notes receivable — affiliated companies	14	18
Materials and supplies	49	41
Natural gas inventory	96	211
Non-trading derivative assets	64	99
Deferred income tax assets	4	1
Prepaid expenses and other current assets	43	90
Total current assets	682	1,319
Property, Plant and Equipment:
Property, plant and equipment	5,605	5,364
Less: accumulated depreciation and amortization	1,645	1,554
Property, plant and equipment, net	3,960	3,810
Other Assets:
Goodwill	840	840
Non-trading derivative assets	33	32
Investment in unconsolidated affiliates	4,471	4,521
Notes receivable from unconsolidated affiliates	363	363
Other	152	160
Total other assets	5,859	5,916
Total Assets	10,501	11,045
Current Liabilities:
Short-term borrowings	24	53
Current portion of long-term debt	325	0
Accounts payable	227	528
Accounts and notes payable — affiliated companies	38	228
Taxes accrued	41	67
Interest accrued	36	36
Customer deposits	78	80
Derivative Liability, Current	7	19
Other	159	137
Total current liabilities	935	1,148
Other Liabilities:
Deferred Tax Liabilities, Net, Noncurrent	2,333	2,252
Non-trading derivative liabilities	6	1
Benefit obligations	110	111
Regulatory liabilities	711	669
Other	195	194
Total other liabilities	3,355	3,227
Long-Term Debt	1,879	2,469
Commitments and Contingencies (Note 10)
Stockholder’s Equity:
Common stock	0	0
Paid-in capital	2,417	2,417
Retained earnings	1,914	1,783
Accumulated other comprehensive income	1	1
Total stockholder’s equity	4,332	4,201
Total Liabilities and Stockholder’s Equity	$ 10,501	$ 11,045

CONDENSED CONSOLIDATED BALANCE SHEETS Balance Sheets Parenthetical - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Allowance for Doubtful Accounts Receivable, Current	$ 25	$ 23

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash Flows from Operating Activities:
Net income	$ 131	$ 200
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	112	100
Amortization of deferred financing costs	5	5
Deferred income taxes	80	116
Write-down of natural gas inventory	2	0
Equity in earnings of unconsolidated affiliates, net of distributions	50	2
Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	442	289
Accounts receivable/payable - affiliated companies	2	18
Inventory	105	(2)
Taxes receivable	0	18
Accounts payable	(298)	(174)
Fuel cost recovery	86	(42)
Interest and taxes accrued	(26)	(32)
Non-trading derivatives, net	2	(11)
Margin deposits, net	25	(2)
Other current assets	10	13
Other current liabilities	(20)	(11)
Other assets	8	13
Other liabilities	14	29
Other, net	1	3
Net cash provided by operating activities	731	532
Cash Flows from Investing Activities:
Capital expenditures	(248)	(227)
Increase in notes receivable - affiliated companies	0	141
Investment in unconsolidated affiliates	0	(1)
Other, net	2	(3)
Net cash used in investing activities	(246)	(372)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(29)	(1)
Payments of commercial paper, net	(269)	(118)
Decrease in notes payable - affiliated companies	(188)	(38)
Other, net	0	1
Net cash used in financing activities	(486)	(156)
Net Increase (Decrease) in Cash and Cash Equivalents	(1)	4
Cash and Cash Equivalents at Beginning of Period	2	1
Cash and Cash Equivalents at End of Period	1	5
Cash Payments:
Interest, net of capitalized interest	64	64
Income taxes (refunds), net	6	(1)
Non-cash transactions:
Accounts payable related to capital expenditures	34	26
Transfer from Investments	$ 1	$ 0

Background and Basis of Presentation	6 Months Ended
Background and Basis of Presentation	Jun. 30, 2015
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, 2014. Background. CERC owns and operates natural gas distribution systems and owns interests in Enable Midstream Partners, LP (Enable) as described in Note 6. A wholly owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and gas utilities. As of June 30, 2015, 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 generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. 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	6 Months Ended
New Accounting Pronouncements	Jun. 30, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	New Accounting Pronouncements In February 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (ASU 2015-02). ASU 2015-02 changes the analysis that reporting organizations must perform to evaluate whether they should consolidate certain legal entities, such as limited partnerships. The changes include, among others, modification of the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities and elimination of the presumption that a general partner should consolidate a limited partnership. ASU 2015-02 does not amend the related party guidance for situations in which power is shared between two or more entities that hold interests in a VIE. ASU 2015-02 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. CERC will adopt ASU 2015-02 on January 1, 2016 and is currently assessing the impact, if any, that this standard will have on its financial position, results of operations, cash flows and disclosures. In April 2015, the FASB issued Accounting Standards Update No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Cost (ASU 2015-03). ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by ASU 2015-03. CERC will adopt ASU 2015-03 retrospectively on January 1, 2016, which will result in a reduction of both other long-term assets and long-term debt on its Condensed Consolidated Balance Sheets. CERC had debt issuance costs of $16 million and $18 million included in other long-term assets on its Condensed Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014, respectively. In April 2015, the FASB issued Accounting Standards Update No. 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) (ASU 2015-05). ASU 2015-05 provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. The guidance will not change a customer’s accounting for service contracts. ASU 2015-05 is effective for fiscal years, and interim periods within the fiscal years, beginning after December 15, 2015 and may be adopted either prospectively or retrospectively. CERC will adopt ASU 2015-05 on January 1, 2016 and is currently assessing the impact that this standard will have on its financial position, results of operations, cash flows and disclosures. In May 2014, the FASB issued Accounting Standards Update 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 was initially 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. In July 2015, the FASB issued Accounting Standard Update, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, which delays the effective date of ASU 2014-09 by one year. CERC is currently evaluating the impact that ASU 2014-09 will have on its financial position, results of operations, cash flows and disclosures, and may adopt ASU 2014-09 on January 1, 2018 as permitted by the new guidance. 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 Employee Benefit Plans

6 Months Ended

Jun. 30, 2015

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

Employee Benefit Plans

CERC’s employees participate in CenterPoint Energy’s postretirement benefit plan. CERC’s net periodic cost includes the following components relating to postretirement benefits:



	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014		2015		2014
	(in millions)
Interest cost on accumulated benefit obligation	1		2		$	2	$	3
Amortization of loss	—		—		1		—
Net periodic cost	$	1	$	2	$	3	$	3

CERC expects to contribute approximately $7 million to its postretirement benefit plan in 2015, of which $1 million and $3 million were contributed during the three and six months ended June 30, 2015, respectively.

Derivative Instruments

6 Months Ended

Jun. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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 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, 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 natural gas distribution business (NGD) in Arkansas, Louisiana, Mississippi and Oklahoma. NGD 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 NGD’s results in Texas and Minnesota, although NGD’s Minnesota division implemented a full decoupling pilot in July 2015, which includes the effects of weather in the calculation.

CERC entered into heating-degree day swaps for certain NGD jurisdictions to mitigate the effect of fluctuations from normal weather on its results of operations and cash flows for the winter heating season, which contained a bilateral dollar cap of $16 million in both 2013–2014 and 2014–2015. The swaps are based on ten-year normal weather. During the three months ended June 30, 2015 and 2014, CERC recognized gains of $1 million and losses of $-0-, respectively, related to these swaps. During the six months ended June 30, 2015 and 2014, CERC recognized losses of $4 million and $7 million, respectively, related to these swaps. Weather hedge gains and losses are included in revenues in the Condensed Statements of Consolidated Income.

(b) Derivative Fair Values and Income Statement Impacts

The following tables present information about CERC’s derivative instruments and hedging activities. The first four tables provide a balance sheet overview of CERC’s Derivative Assets and Liabilities as of June 30, 2015 and December 31, 2014, while the last two tables provide a breakdown of the related income statement impacts for the three and six months ended June 30, 2015 and 2014.



Fair Value of Derivative Instruments
		June 30, 2015
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2)	Current Assets: Non-trading derivative assets	$	66	$	2
Natural gas derivatives (1) (2)	Other Assets: Non-trading derivative assets	33		—
Natural gas derivatives (1) (2)	Current Liabilities: Non-trading derivative liabilities	8		43
Natural gas derivatives (1) (2)	Other Liabilities: Non-trading derivative liabilities	2		19
Total		$	109	$	64

________________


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 718 billion cubic feet (Bcf) or a net 77 Bcf long position. Of the net long position, basis swaps constitute 118 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 $84 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 $39 million.



Offsetting of Natural Gas Derivative Assets and Liabilities
	June 30, 2015
	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	$	74		$	(10	)	$	64
Other Assets: Non-trading derivative assets	35			(2		)	33
Current Liabilities: Non-trading derivative liabilities	(45		)	38			(7		)
Other Liabilities: Non-trading derivative liabilities	(19		)	13			(6		)
Total	$	45		$	39		$	84

________________


(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, 2014
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2)	Current Assets: Non-trading derivative assets	$	101	$	1
Natural gas derivatives (1) (2)	Other Assets: Non-trading derivative assets	32		—
Natural gas derivatives (1) (2)	Current Liabilities: Non-trading derivative liabilities	14		83
Natural gas derivatives (1) (2)	Other Liabilities: Non-trading derivative liabilities	2		18
Total		$	149	$	102

________________


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 804 Bcf or a net 60 Bcf long position. Of the net long position, basis swaps constitute 127 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 $111 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 $64 million.



Offsetting of Natural Gas Derivative Assets and Liabilities
	December 31, 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	$	115		$	(16	)	$	99
Other Assets: Non-trading derivative assets	34			(2		)	32
Current Liabilities: Non-trading derivative liabilities	(84		)	65			(19		)
Other Liabilities: Non-trading derivative liabilities	(18		)	17			(1		)
Total	$	47		$	64		$	111

________________


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


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

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



Income Statement Impact of Derivative Activity
		Three Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2015		2014
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenue	$	7	$	5
Natural gas derivatives (1)	Gains (Losses) in Expense: Natural Gas	1		4
Total		$	8	$	9

________________


(1)	The Gains (Losses) in Expense: Natural Gas includes $-0- during each of the three months ended June 30, 2015 and 2014, related to physical forwards purchased from Enable.



Income Statement Impact of Derivative Activity
		Six Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2015			2014
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenue	$	49		$	(96	)
Natural gas derivatives (1)	Gains (Losses) in Expense: Natural Gas	(42		)	114
Total		$	7		$	18

________________


(1)	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the six months ended June 30, 2015 and 2014, respectively, related to physical forwards purchased from Enable.

CERC enters into financial derivative contracts containing material adverse change provisions. These provisions could require CERC to post additional collateral if the Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. credit ratings of CERC are downgraded. The total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position at both June 30, 2015 and December 31, 2014 was $2 million. CERC posted no assets as collateral towards derivative instruments that contain credit risk contingent features at either June 30, 2015 or December 31, 2014. If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered at both June 30, 2015 and December 31, 2014, $2 million of additional assets would be required to be posted as collateral.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624171-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41620-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624163-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5579240-113959

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4D
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624177-113959

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80784-113994

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41641-113959

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5579245-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4H
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624258-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80748-113994

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5708775-113959

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5708773-113959

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5618551-113959

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5580258-113959

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4E
-URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624181-113959

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41638-113959

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Fair Value Measurements

6 Months Ended

Jun. 30, 2015

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. At June 30, 2015, 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 $1.26 to $3.79 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 71%) as an unobservable input. CERC’s Level 3 derivative assets and liabilities consist of both long and short positions (forwards and options) and their fair value is sensitive to forward prices and volatilities. If forward prices decrease, CERC’s long forwards lose value whereas its short forwards gain in value. If volatility decreases, CERC’s long options lose value whereas its short options gain in value.

CERC determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period. For the six months ended June 30, 2015, there were no transfers between Level 1 and 2. CERC also recognizes purchases of Level 3 financial assets and liabilities at their fair market value at the end of the reporting period.

The following tables present information about CERC’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014, and indicate the fair value hierarchy of the valuation techniques utilized by CERC to determine such fair value.



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of June 30, 2015
	(in millions)
Assets
Corporate equities	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11
Natural gas derivatives	2		96		11		(12		)	97
Total assets	$	15	$	96	$	11	$	(12	)	$	110
Liabilities
Natural gas derivatives	$	10	$	53	$	1	$	(51	)	$	13
Total liabilities	$	10	$	53	$	1	$	(51	)	$	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 $39 million posted with the same counterparties.


(2)	Amounts are included in Prepaid Expenses and Other Current Assets in the Condensed Consolidated Balance Sheets.



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of December 31, 2014
	(in millions)
Assets
Corporate equities	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11
Natural gas derivatives	7		122		20		(18		)	131
Total assets	$	20	$	122	$	20	$	(18	)	$	144
Liabilities
Natural gas derivatives	$	22	$	77	$	3	$	(82	)	$	20
Total liabilities	$	22	$	77	$	3	$	(82	)	$	20

________________


(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 $64 million posted with the same counterparties.


(2)	Amounts are included in Prepaid Expenses and Other Current Assets in the Condensed Consolidated Balance Sheets.

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



	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Assets and Liabilities, net
	Three Months Ended June 30,					Six Months Ended June 30,
	2015			2014		2015			2014
	(in millions)
Beginning balance	$	13		$	1	$	17		$	3
Total gains	—			2		—			—
Total settlements	(3		)	1		(6		)	2
Transfers into Level 3	—			—		—			(1		)
Transfers out of Level 3	—			—		(1		)	—
Ending balance ⁽¹⁾	$	10		$	4	$	10		$	4
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	—		$	1	$	2		$	2

____________


(1)	CERC did not have significant Level 3 purchases or sales during either of the three or six months ended June 30, 2015 or 2014.

Estimated Fair Value of Financial Instruments

The fair values of cash and cash equivalents and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. Non-trading derivative assets and liabilities are stated at fair value and are excluded from the table below. The fair value of each debt instrument is determined by multiplying the principal amount of each debt instrument by the market price. These assets and liabilities, which are not measured at fair value in the Condensed Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 or Level 2 in the fair value hierarchy.



	June 30, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial assets:
Notes receivable from unconsolidated affiliates	$	363	$	363	$	363	$	362
Financial liabilities:
Long-term debt	$	2,204	$	2,433	$	2,469	$	2,772

- Definition

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

+ References + Details

Unconsolidated Affiliates (Notes)

6 Months Ended

Jun. 30, 2015

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. and ArcLight Capital Partners, LLC 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.

CERC’s maximum exposure to loss related to Enable, a VIE in which CERC is not the primary beneficiary, is limited to its equity investment as presented in the Condensed Consolidated Balance Sheet at June 30, 2015, 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 during each of the three months ended June 30, 2015 and 2014, and $4 million during each of the six months ended June 30, 2015 and 2014, and had interest receivable from Enable of $5 million and $4 million as of June 30, 2015 and December 31, 2014, respectively, on its notes receivable.

Effective on the Closing Date, CenterPoint Energy and Enable entered into a Services Agreement, Employee Transition Agreement, Transitional Seconding Agreement and other agreements (Transition Agreements). Under the Services Agreement, CERC agreed to provide certain support services to Enable such as accounting, legal, risk management and treasury functions for an initial term. The initial term of the Services Agreement ends on April 30, 2016, after which date such services continue on a year-to-year basis unless terminated by Enable with at least 90 days’ notice. Enable may terminate the Services Agreement, or the provision of any services thereunder, upon approval by its board of directors and at least 180 days’ notice.

CERC provided seconded employees to Enable to support its operations for a term ending on December 31, 2014. Enable, at its discretion, had the right to select and offer employment to seconded employees from CERC. During the fourth quarter of 2014, Enable notified CERC that it provided employment offers to substantially all of the seconded employees from CERC. Substantially all of the seconded employees became employees of Enable effective January 1, 2015.

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 on the Closing Date, under which CERC would contribute its retained interest in SESH, in exchange for a specified number of limited partner common 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 exercisable with respect to (1) a 24.95% interest in SESH, which closed on May 30, 2014 and (2) a 0.1% interest in SESH, which closed on June 30, 2015.

CERC billed Enable for reimbursement of transition services, including the costs of seconded employees, $2 million and $37 million during the three months ended June 30, 2015 and 2014, respectively, and $7 million and $82 million during the six months ended June 30, 2015 and 2014, respectively, under the Transition Agreements. Actual transition services costs are recorded net of reimbursements received from Enable. CERC had accounts receivable from Enable of $4 million and $28 million as of June 30, 2015 and December 31, 2014, respectively, for amounts billed for transition services, including the cost of seconded employees.

CERC incurred natural gas expenses, including transportation and storage costs, of $26 million and $27 million during the three months ended June 30, 2015 and 2014, respectively, and $65 million and $75 million during the six months ended June 30, 2015 and 2014, respectively, for transactions with Enable. CERC had accounts payable to Enable of $7 million and $23 million at June 30, 2015 and December 31, 2014, respectively, from such transactions.

As of June 30, 2015, CERC held an approximate 55.4% limited partner interest in Enable, consisting of 94,151,707 common units and 139,704,916 subordinated units.

CERC evaluates its equity method investments for impairment when factors indicate that a decrease in value of its investment has occurred and the carrying amount of its investment may not be recoverable. An impairment loss, based on the excess of the carrying value over the best estimate of fair value of the investment, is recognized in earnings when an impairment is deemed to be other than temporary. Considerable judgment is used in determining if an impairment loss is other than temporary and the amount of any impairment.

Based on an analysis of its investment in Enable as of June 30, 2015, CERC believes that the decline in the value of its investment is temporary, and that the carrying value of its investment of $4.5 billion will be recovered. CERC considered the severity and duration of the impairment, management’s intent and ability to hold its investment to recovery, significant events and conditions of Enable, including its investment grade credit rating and planned expansion projects, along with other factors, to conclude that its investment is not other than temporarily impaired as of June 30, 2015. A sustained low Enable common unit price or further declines in such price could result in CERC recording an impairment charge in future periods. If the decrease in value of CERC’s investment in Enable is determined to be other than temporary, an impairment will be recognized equal to the excess of the carrying value of CERC’s investment in Enable over its estimated fair value. Both the income approach and market approach would be utilized to estimate the fair value of CERC’s total investment in Enable, which includes CERC’s limited partner common and subordinated units, general partner interest and incentive distribution rights. The determination of fair value will consider a number of relevant factors including Enable’s forecasted results, recent comparable transactions and the limited float of Enable’s publicly traded common units. As of June 30, 2015, the carrying value of our investment in Enable was $19.12 per unit. On June 30, 2015, Enable’s common unit price closed at $15.98, based on its publicly traded common units which represent approximately 7% of total outstanding units, (an aggregate of approximately $734 million below carrying value). On July 31, 2015, Enable’s common unit price closed at $16.36 (approximately $645 million below carrying value).

Investment in Unconsolidated Affiliates:



	June 30, 2015		December 31, 2014
	(in millions)
Enable	$	4,471	$	4,520
SESH (1)	—		1
Total	$	4,471	$	4,521


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Equity in Earnings of Unconsolidated Affiliates, net:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	43	$	69	$	95	$	157
SESH (1)	—		2		—		5
Total	$	43	$	71	$	95	$	162


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Operating revenues	$	590	$	826	$	1,206	$	1,828
Cost of sales, excluding depreciation and amortization	277		478		569		1,111
Operating income	93		139		197		301
Net income attributable to Enable	77		120		168		269

CERC’s interest	$	42	$	67	$	93	$	154
Basis difference accretion	1		2		2		3
CERC’s equity in earnings, net	$	43	$	69	$	95	$	157

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



	June 30, 2015			December 31, 2014
	(in millions)
Current assets	$	414		$	438
Non-current assets	11,766			11,399
Current liabilities	834			671
Non-current liabilities	2,611			2,343
Non-controlling interest	31			31
Enable partners’ capital	8,704			8,792

CERC’s ownership interest in Enable partners’ capital	$	4,817		$	4,869

CERC’s basis difference attributable to goodwill (1)	(217		)	(217		)
CERC’s accretable basis difference (2)	(129		)	(132		)
CERC’s total basis difference	(346		)	(349		)
CERC’s investment in Enable	$	4,471		$	4,520


(1)	The difference relates to CERC’s proportionate share of Enable’s goodwill arising from its acquisition of Enogex LLC, and therefore will be recognized by CERC upon dilution or disposition of its interest in Enable.


(2)	The difference will be recognized by CERC over 30 years beginning May 1, 2013. CERC will also adjust the accretable basis difference for dilution or disposition of its interest in Enable.

Distributions Received from Unconsolidated Affiliates:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	73	$	90	$	145	$	157
SESH (1)	—		4		—		7
Total	$	73	$	94	$	145	$	164


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Goodwill

6 Months Ended

Jun. 30, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets Disclosure [Text Block]

Goodwill

Goodwill by reportable business segment as of both June 30, 2015 and December 31, 2014 is as follows (in millions):



Natural Gas Distribution	$	746
Energy Services	83
Other Operations	11
Total	$	840

- Definition

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

+ References + Details

Related Party Transactions

6 Months Ended

Jun. 30, 2015

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 borrowings from the money pool of $-0- and $188 million at June 30, 2015 and December 31, 2014, respectively, which are included in accounts and notes payable-affiliated companies in the Consolidated Balance Sheets. Net interest income (expense) related to accounts and notes payables-affiliated companies was not material for either the three or six months ended June 30, 2015 or 2014.

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 as follows and are included primarily in operation and maintenance expenses:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Corporate service charges	$	31	$	31	$	59	$	59

See Note 6 for related party transactions with Enable.

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References + Details

Short-term Borrowings and Long-term Debt

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Short-term Borrowings and Long-term Debt

(a)Short-term Borrowings

Inventory Financing. NGD has asset management agreements associated with its utility distribution service in Arkansas, north Louisiana and Oklahoma that extend through 2018. Pursuant to the provisions of the agreements, NGD sells natural gas and agrees to repurchase an equivalent amount of natural gas during the winter heating seasons at the same cost, plus a financing charge. These transactions are accounted for as a financing and they had an associated principal obligation of $24 million and $53 million as of June 30, 2015 and December 31, 2014, respectively.


(b)	Long-term Debt

Revolving Credit Facility. As of June 30, 2015 and December 31, 2014, CERC had the following revolving credit facility and utilization of such facility (in millions):



		June 30, 2015						December 31, 2014
Size of Facility		Loans		Letters of Credit		Commercial Paper		Loans		Letters of Credit		Commercial Paper
$	600	$	—	$	—	$	72	$	—	$	—	$	341

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 as of June 30, 2015.

Commitments and Contingencies	6 Months Ended
Commitments and Contingencies	Jun. 30, 2015
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 Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014 as these contracts meet an exception as “normal purchases contracts” or do not meet the definition of a derivative. Natural gas supply commitments also include natural gas transportation contracts that do not meet the definition of a derivative. As of June 30, 2015, minimum payment obligations for natural gas supply commitments are approximately $228 million for the remaining six months in 2015, $485 million in 2016, $471 million in 2017, $419 million in 2018, $227 million in 2019 and $130 million after 2019. (b) Legal, Environmental and Other Regulatory Matters Legal Matters Gas Market Manipulation Cases. CenterPoint Energy, CenterPoint Energy Houston Electric, LLC (CenterPoint Houston) 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, and stayed the remainder of the case pending outcome of the appeals. The plaintiffs appealed this ruling to the U.S. Court of Appeals for the Ninth Circuit, which reversed the trial court’s dismissal of the plaintiffs’ claims. The U.S. Supreme Court agreed to review the case, and on April 21, 2015, affirmed the Ninth Circuit’s ruling and remanded the case to the district court for further proceedings. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims on remand. CERC does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows. Environmental Matters Manufactured Gas Plant Sites. CERC and its predecessors operated manufactured gas plants (MGPs) in the past. There are seven MGP sites in CERC’s Minnesota service territory. CERC believes it never owned or operated, and therefore has no liability with respect to, two of these sites. With respect to two other sites, CERC has completed state-ordered remediation, other than ongoing monitoring and water treatment. At June 30, 2015, CERC had a recorded liability of $7 million for remediation of these five Minnesota sites. The estimated range of possible remediation costs for the sites for which CERC believes it may have responsibility was $4 million to $28 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. In addition to the Minnesota sites, the U.S. Environmental Protection Agency and other regulators have investigated MGP sites that were owned or operated by CERC or that may have been owned by one of its former affiliates. CERC and CenterPoint Energy do not expect the ultimate outcome of these investigations to have a material adverse effect on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC. Asbestos. Some facilities owned by 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 $36 million as of June 30, 2015. 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	6 Months Ended
Income Taxes	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rate reported for the three months ended June 30, 2015 was 35% compared to 38% for the same period in 2014. The lower effective tax rate for the three months ended June 30, 2015 was primarily due to the lower Texas tax rate enacted on June 15, 2015. The effective tax rate reported for the six months ended June 30, 2015 and 2014 was 39% and 38%, respectively. CERC reported no uncertain tax liability as of June 30, 2015 and expects no significant change to the uncertain tax liability over the twelve-month period ending June 30, 2016. Tax years through 2011 have been audited and settled with the Internal Revenue Service (IRS). CenterPoint Energy’s consolidated federal income tax returns for the years 2012 and 2013 are currently under audit by the IRS. For 2014 and 2015, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

Reportable Business Segments

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

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 of CERC’s investment in Enable. The Other Operations business segment includes unallocated corporate costs and inter-segment eliminations.

Financial data for business segments is as follows (in millions):



	For the Three Months Ended June 30, 2015
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)
Natural Gas Distribution	$	420	$	7		$	19
Energy Services	404		4			9
Midstream Investments (1)	—		—			—
Other Operations	—		—			(1		)
Reconciling Eliminations	—		(11		)	—
Consolidated	$	824	$	—		$	27



	For the Three Months Ended June 30, 2014
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)
Natural Gas Distribution	$	526	$	6		$	30
Energy Services	657		19			11
Midstream Investments (1)	—		—			—
Other Operations	—		—			(2		)
Reconciling Eliminations	—		(25		)	—
Consolidated	$	1,183	$	—		$	39



	For the Six Months Ended June 30, 2015
	Revenues from External Customers		Inter-segment Revenues			Operating Income		Total Assets as of June 30, 2015
Natural Gas Distribution	$	1,605	$	15		$	165	$	5,301
Energy Services	1,036		22			22		837
Midstream Investments (1)	—		—			—		4,471
Other Operations	—		—			—		715
Reconciling Eliminations	—		(37		)	—		(823		)
Consolidated	$	2,641	$	—		$	187	$	10,501



	For the Six Months Ended June 30, 2014
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)			Total Assets as of December 31, 2014
Natural Gas Distribution	$	2,004	$	15		$	192		$	5,464
Energy Services	1,709		51			37			978
Midstream Investments (1)	—		—			—			4,521
Other Operations	1		—			(2		)	1,046
Reconciling Eliminations	—		(66		)	—			(964		)
Consolidated	$	3,714	$	—		$	227		$	11,045


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



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	43	$	69	$	95	$	157
SESH	—		2		—		5
Total	$	43	$	71	$	95	$	162

Midstream Investments’ total assets are as follows:



	June 30, 2015		December 31, 2014
	(in millions)
Enable	$	4,471	$	4,520
SESH	—		1
Total	$	4,471	$	4,521

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

+ Details

Other Current Assets and Liabilities	6 Months Ended
Other Current Assets and Liabilities	Jun. 30, 2015
Other Current Assets and Liabilities [Abstract]
Other Current Assets and Liabilities [Text Block]	Other Current Assets and Liabilities Included in other current assets on the Condensed Consolidated Balance Sheets at June 30, 2015 and December 31, 2014 were $19 million and $19 million, respectively, of margin deposits and $4 million and $45 million, respectively, of under-recovered gas cost. Included in other current liabilities on the Condensed Consolidated Balance Sheets at June 30, 2015 and December 31, 2014 were $89 million and $37 million, respectively, of over-recovered gas cost.

Subsequent Events (Notes)	6 Months Ended
Subsequent Events (Notes)	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events On July 22, 2015, Enable declared a quarterly cash distribution of $0.316 per unit on all of its outstanding common and subordinated units for the quarter ended June 30, 2015. Accordingly, CERC Corp. expects to receive a cash distribution of approximately $74 million from Enable in the third quarter of 2015 to be made with respect to CERC Corp.’s limited partner interest in Enable for the second quarter of 2015.

Employee Benefit Plans Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2015

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

CERC’s employees participate in CenterPoint Energy’s postretirement benefit plan. CERC’s net periodic cost includes the following components relating to postretirement benefits:



	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014		2015		2014
	(in millions)
Interest cost on accumulated benefit obligation	1		2		$	2	$	3
Amortization of loss	—		—		1		—
Net periodic cost	$	1	$	2	$	3	$	3

Derivative Instruments Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Instruments Table



Fair Value of Derivative Instruments
		June 30, 2015
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2)	Current Assets: Non-trading derivative assets	$	66	$	2
Natural gas derivatives (1) (2)	Other Assets: Non-trading derivative assets	33		—
Natural gas derivatives (1) (2)	Current Liabilities: Non-trading derivative liabilities	8		43
Natural gas derivatives (1) (2)	Other Liabilities: Non-trading derivative liabilities	2		19
Total		$	109	$	64

________________


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 718 billion cubic feet (Bcf) or a net 77 Bcf long position. Of the net long position, basis swaps constitute 118 Bcf.

(2)



Offsetting of Natural Gas Derivative Assets and Liabilities
	June 30, 2015
	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	$	74		$	(10	)	$	64
Other Assets: Non-trading derivative assets	35			(2		)	33
Current Liabilities: Non-trading derivative liabilities	(45		)	38			(7		)
Other Liabilities: Non-trading derivative liabilities	(19		)	13			(6		)
Total	$	45		$	39		$	84

________________


(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, 2014
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value
		(in millions)
Natural gas derivatives (1) (2)	Current Assets: Non-trading derivative assets	$	101	$	1
Natural gas derivatives (1) (2)	Other Assets: Non-trading derivative assets	32		—
Natural gas derivatives (1) (2)	Current Liabilities: Non-trading derivative liabilities	14		83
Natural gas derivatives (1) (2)	Other Liabilities: Non-trading derivative liabilities	2		18
Total		$	149	$	102

________________


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 804 Bcf or a net 60 Bcf long position. Of the net long position, basis swaps constitute 127 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 $111 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 $64 million.



Offsetting of Natural Gas Derivative Assets and Liabilities
	December 31, 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	$	115		$	(16	)	$	99
Other Assets: Non-trading derivative assets	34			(2		)	32
Current Liabilities: Non-trading derivative liabilities	(84		)	65			(19		)
Other Liabilities: Non-trading derivative liabilities	(18		)	17			(1		)
Total	$	47		$	64		$	111

________________


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


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

Income Statement Impact of Derivative Activity Table



Income Statement Impact of Derivative Activity
		Three Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2015		2014
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenue	$	7	$	5
Natural gas derivatives (1)	Gains (Losses) in Expense: Natural Gas	1		4
Total		$	8	$	9

________________


(1)	The Gains (Losses) in Expense: Natural Gas includes $-0- during each of the three months ended June 30, 2015 and 2014, related to physical forwards purchased from Enable.



Income Statement Impact of Derivative Activity
		Six Months Ended June 30,
Total derivatives not designated as hedging instruments	Income Statement Location	2015			2014
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenue	$	49		$	(96	)
Natural gas derivatives (1)	Gains (Losses) in Expense: Natural Gas	(42		)	114
Total		$	7		$	18

________________


(1)	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the six months ended June 30, 2015 and 2014, respectively, related to physical forwards purchased from Enable.

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2015

Fair Value Disclosures [Abstract]

Fair Value, Assets Measured on Recurring Basis [Table Text Block]



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of June 30, 2015
	(in millions)
Assets
Corporate equities	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11
Natural gas derivatives	2		96		11		(12		)	97
Total assets	$	15	$	96	$	11	$	(12	)	$	110
Liabilities
Natural gas derivatives	$	10	$	53	$	1	$	(51	)	$	13
Total liabilities	$	10	$	53	$	1	$	(51	)	$	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 $39 million posted with the same counterparties.


(2)	Amounts are included in Prepaid Expenses and Other Current Assets in the Condensed Consolidated Balance Sheets.



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of December 31, 2014
	(in millions)
Assets
Corporate equities	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11
Natural gas derivatives	7		122		20		(18		)	131
Total assets	$	20	$	122	$	20	$	(18	)	$	144
Liabilities
Natural gas derivatives	$	22	$	77	$	3	$	(82	)	$	20
Total liabilities	$	22	$	77	$	3	$	(82	)	$	20

________________


(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 $64 million posted with the same counterparties.


(2)	Amounts are included in Prepaid Expenses and Other Current Assets in the Condensed Consolidated Balance Sheets.

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]



	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Assets and Liabilities, net
	Three Months Ended June 30,					Six Months Ended June 30,
	2015			2014		2015			2014
	(in millions)
Beginning balance	$	13		$	1	$	17		$	3
Total gains	—			2		—			—
Total settlements	(3		)	1		(6		)	2
Transfers into Level 3	—			—		—			(1		)
Transfers out of Level 3	—			—		(1		)	—
Ending balance ⁽¹⁾	$	10		$	4	$	10		$	4
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	—		$	1	$	2		$	2

____________


(1)	CERC did not have significant Level 3 purchases or sales during either of the three or six months ended June 30, 2015 or 2014.

Fair Value, by Balance Sheet Grouping [Table Text Block]

Estimated Fair Value of Financial Instruments



	June 30, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial assets:
Notes receivable from unconsolidated affiliates	$	363	$	363	$	363	$	362
Financial liabilities:
Long-term debt	$	2,204	$	2,433	$	2,469	$	2,772

Unconsolidated Affiliates (Tables)

6 Months Ended

Jun. 30, 2015

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Investment in Unconsolidated Affiliates:



	June 30, 2015		December 31, 2014
	(in millions)
Enable	$	4,471	$	4,520
SESH (1)	—		1
Total	$	4,471	$	4,521


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Equity in Earnings of Unconsolidated Affiliates, net:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	43	$	69	$	95	$	157
SESH (1)	—		2		—		5
Total	$	43	$	71	$	95	$	162


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Summarized unaudited consolidated income information for Enable is as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Operating revenues	$	590	$	826	$	1,206	$	1,828
Cost of sales, excluding depreciation and amortization	277		478		569		1,111
Operating income	93		139		197		301
Net income attributable to Enable	77		120		168		269

CERC’s interest	$	42	$	67	$	93	$	154
Basis difference accretion	1		2		2		3
CERC’s equity in earnings, net	$	43	$	69	$	95	$	157

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



	June 30, 2015			December 31, 2014
	(in millions)
Current assets	$	414		$	438
Non-current assets	11,766			11,399
Current liabilities	834			671
Non-current liabilities	2,611			2,343
Non-controlling interest	31			31
Enable partners’ capital	8,704			8,792

CERC’s ownership interest in Enable partners’ capital	$	4,817		$	4,869

CERC’s basis difference attributable to goodwill (1)	(217		)	(217		)
CERC’s accretable basis difference (2)	(129		)	(132		)
CERC’s total basis difference	(346		)	(349		)
CERC’s investment in Enable	$	4,471		$	4,520


(1)	The difference relates to CERC’s proportionate share of Enable’s goodwill arising from its acquisition of Enogex LLC, and therefore will be recognized by CERC upon dilution or disposition of its interest in Enable.


(2)	The difference will be recognized by CERC over 30 years beginning May 1, 2013. CERC will also adjust the accretable basis difference for dilution or disposition of its interest in Enable.

Distributions Received from Unconsolidated Affiliates:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	73	$	90	$	145	$	157
SESH (1)	—		4		—		7
Total	$	73	$	94	$	145	$	164


(1)	CERC disposed of its remaining interest in SESH on June 30, 2015.

Goodwill Goodwill (Tables)

6 Months Ended

Jun. 30, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill [Table Text Block]

Goodwill by reportable business segment as of both June 30, 2015 and December 31, 2014 is as follows (in millions):



Natural Gas Distribution	$	746
Energy Services	83
Other Operations	11
Total	$	840

Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2015



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Corporate service charges	$	31	$	31	$	59	$	59

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

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

Revolving Credit Facility. As of June 30, 2015 and December 31, 2014, CERC had the following revolving credit facility and utilization of such facility (in millions):



		June 30, 2015						December 31, 2014
Size of Facility		Loans		Letters of Credit		Commercial Paper		Loans		Letters of Credit		Commercial Paper
$	600	$	—	$	—	$	72	$	—	$	—	$	341

Reportable Business Segments (Tables)

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

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

inancial data for business segments is as follows (in millions):



	For the Three Months Ended June 30, 2015
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)
Natural Gas Distribution	$	420	$	7		$	19
Energy Services	404		4			9
Midstream Investments (1)	—		—			—
Other Operations	—		—			(1		)
Reconciling Eliminations	—		(11		)	—
Consolidated	$	824	$	—		$	27



	For the Three Months Ended June 30, 2014
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)
Natural Gas Distribution	$	526	$	6		$	30
Energy Services	657		19			11
Midstream Investments (1)	—		—			—
Other Operations	—		—			(2		)
Reconciling Eliminations	—		(25		)	—
Consolidated	$	1,183	$	—		$	39



	For the Six Months Ended June 30, 2015
	Revenues from External Customers		Inter-segment Revenues			Operating Income		Total Assets as of June 30, 2015
Natural Gas Distribution	$	1,605	$	15		$	165	$	5,301
Energy Services	1,036		22			22		837
Midstream Investments (1)	—		—			—		4,471
Other Operations	—		—			—		715
Reconciling Eliminations	—		(37		)	—		(823		)
Consolidated	$	2,641	$	—		$	187	$	10,501



	For the Six Months Ended June 30, 2014
	Revenues from External Customers		Inter-segment Revenues			Operating Income (Loss)			Total Assets as of December 31, 2014
Natural Gas Distribution	$	2,004	$	15		$	192		$	5,464
Energy Services	1,709		51			37			978
Midstream Investments (1)	—		—			—			4,521
Other Operations	1		—			(2		)	1,046
Reconciling Eliminations	—		(66		)	—			(964		)
Consolidated	$	3,714	$	—		$	227		$	11,045

Midstream Investments [Table Text Block]

Midstream Investments’ equity earnings are as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(in millions)
Enable	$	43	$	69	$	95	$	157
SESH	—		2		—		5
Total	$	43	$	71	$	95	$	162

Midstream Investments’ total assets are as follows:



	June 30, 2015		December 31, 2014
	(in millions)
Enable	$	4,471	$	4,520
SESH	—		1
Total	$	4,471	$	4,521

Background and Basis of Presentation (Details)	Jun. 30, 2015
Enable Midstream Partners [Member]
Equity Method Investment, Ownership Percentage	55.40%

New Accounting Pronouncements (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Other Noncurrent Assets [Member]
Unamortized Debt Issuance Expense	$ 16	$ 18

Employee Benefit Plans Employee Benefit Plans (Details) - Other Postretirement Benefit Plans, Defined Benefit [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Defined Benefit Plan Disclosure [Line Items]
Interest cost on accumulated benefit obligation	$ 1	$ 2	$ 2	$ 3
Amortization of loss	0	0	1	0
Net periodic cost	1	$ 2	3	$ 3
Contribution expected in 2013			7
Contribution made in period	$ 1		$ 3

Derivative Instruments Derivatives and Hedging (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Term of normal weather used as the basis for weather hedges (in years)			10
Weather Hedge Swaps [Member] \| Sales [Member]
Gains (Losses) Recognized Related to Weather Hedges	$ 1	$ 0	$ (4)	$ (7)
Natural Gas Distribution \| 2014To2015 [Member]
Weather Hedge, Bilateral Cap Amount			16
Natural Gas Distribution \| 2013To2014 [Member]
Weather Hedge, Bilateral Cap Amount			$ 16

Derivative Instruments Derivative Instruments (Details)
MMcf in Thousands, $ in Millions

3 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2015

USD ($)

Jun. 30, 2014

USD ($)

Jun. 30, 2015

USD ($)

MMcf

Jun. 30, 2014

USD ($)

Dec. 31, 2014

USD ($)

MMcf

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

Derivative Instruments, Assets, Physical Forwards Purchased

$ 109

$ 149

Derivative Liability, Fair Value, Gross Liability

102

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

$ 9

$ 18

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

Collateral Already Posted, Aggregate Fair Value

Credit Risk Contingent Feature assets

$ 2

Energy Related Derivative [Member]

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

Derivative, Nonmonetary Notional Amount, Volume | MMcf

718

804

Gross Amounts Recognized (1)

^[1]

$ 45

$ 47

Derivative, Fair Value, Offsets, Net

Derivative Assets (Liabilities), at Fair Value, Net

^[2]

111

collateral Netting

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

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

^[1]

115

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

(10)

(16)

Derivative Asset

^[2]

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

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

^[1]

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

(2)

Derivative Asset

^[2]

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

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

^[1]

(45)

(84)

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

Derivative Liability

^[2]

(7)

(19)

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

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

^[1]

(19)

(18)

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

Derivative Liability

^[2]

(6)

(1)

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

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

(96)

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

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

^[3]

(42)

^[4]

114

^[4]

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

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

Derivative Instruments, Assets, Physical Forwards Purchased

^[5],[6]

101

^[7],[8]

Derivative Liability, Fair Value, Gross Liability

^[5],[6]

^[7],[8]

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

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

Derivative Instruments, Assets, Physical Forwards Purchased

^[5],[6]

^[7],[8]

Derivative Liability, Fair Value, Gross Liability

^[5],[6]

^[7],[8]

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

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

Derivative Instruments, Assets, Physical Forwards Purchased

^[5],[6]

^[7],[8]

Derivative Liability, Fair Value, Gross Liability

^[5],[6]

^[7],[8]

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

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

Derivative Instruments, Assets, Physical Forwards Purchased

^[5],[6]

^[7],[8]

Derivative Liability, Fair Value, Gross Liability

^[5],[6]

$ 19

^[5],[6]

$ 18

^[7],[8]

Long [Member] | Energy Related Derivative [Member]

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

Derivative, Nonmonetary Notional Amount, Volume | MMcf

Swap [Member] | Long [Member] | Energy Related Derivative [Member]

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

Derivative, Nonmonetary Notional Amount, Volume | MMcf

118

127

Enable Midstream Partners [Member] | Forward Contracts [Member] | Energy Related Derivative [Member] | Gains (Losses) in Expense: Natural Gas [Member]

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

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

$ 0

$ 2

[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]	The Gains (Losses) in Expense: Natural Gas includes $-0- during each of the three months ended June 30, 2015 and 2014, related to physical forwards purchased from Enable.
[4]	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the six months ended June 30, 2015 and 2014, respectively, related to physical forwards purchased from Enable.
[5]	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 $84 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 $39 million.
[6]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 718 billion cubic feet (Bcf) or a net 77 Bcf long position. Of the net long position, basis swaps constitute 118 Bcf.
[7]	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 $111 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 $64 million.
[8]	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 804 Bcf or a net 60 Bcf long position. Of the net long position, basis swaps constitute 127 Bcf.

Fair Value Measurements (Details)

3 Months Ended

6 Months Ended

Jun. 30, 2015

USD ($)

Jun. 30, 2014

USD ($)

Jun. 30, 2015

USD ($)

Jun. 30, 2014

USD ($)

Dec. 31, 2014

USD ($)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value, Assets, Level 1 to Level 2 Transfers, Amount

$ 0

Fair Value, Assets, Level 2 to Level 1 Transfers, Amount

Fair Value, Liabilities, Level 1 to Level 2 Transfers, Amount

Fair Value, Liabilities, Level 2 to Level 1 Transfers, Amount

ASSETS

Natural gas derivatives, netting adjustment

(12,000,000)

^[1]

(12,000,000)

^[1]

$ (18,000,000)

^[2]

Total assets

110,000,000

144,000,000

Liabilities [Abstract]

Natural gas derivatives, netting adjustment

(51,000,000)

^[1]

(51,000,000)

^[1]

(82,000,000)

^[2]

Liabilities, Fair Value Disclosure, Recurring

13,000,000

20,000,000

Cash collateral posted with counterparties

39,000,000

64,000,000

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]

Beginning balance

13,000,000

$ 1,000,000

17,000,000

$ 3,000,000

Total gains

2,000,000

Total settlements

(3,000,000)

1,000,000

(6,000,000)

2,000,000

Transfers into Level 3

(1,000,000)

Transfers out of Level 3

(1,000,000)

Ending balance (1)

^[3]

10,000,000

4,000,000

10,000,000

4,000,000

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date

$ 1,000,000

2,000,000

$ 2,000,000

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

Long-term debt

2,204,000,000

2,469,000,000

Fair Value [Member]

Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation Roll Forward

Notes receivable from unconsolidated affiliates

363,000,000

362,000,000

Long-term debt

2,433,000,000

2,772,000,000

Fair Value, Inputs, Level 1 [Member]

ASSETS

Total assets

15,000,000

20,000,000

Liabilities [Abstract]

Liabilities, Fair Value Disclosure, Recurring

10,000,000

22,000,000

Fair Value, Inputs, Level 2 [Member]

ASSETS

Total assets

96,000,000

122,000,000

Liabilities [Abstract]

Liabilities, Fair Value Disclosure, Recurring

53,000,000

77,000,000

Fair Value, Inputs, Level 3 [Member]

ASSETS

Total assets

11,000,000

20,000,000

Liabilities [Abstract]

Liabilities, Fair Value Disclosure, Recurring

1,000,000

$ 1,000,000

3,000,000

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

1.26

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

3.79

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

71.00%

Fair Value, Measurements, Recurring [Member]

ASSETS

Corporate equities

2,000,000

$ 2,000,000

2,000,000

Investments, including money market funds

^[4]

11,000,000

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

ASSETS

Corporate equities

2,000,000

Investments, including money market funds

^[4]

11,000,000

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

ASSETS

Corporate equities

Investments, including money market funds

^[4]

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

ASSETS

Corporate equities

Investments, including money market funds

^[4]

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

ASSETS

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

(12,000,000)

^[1]

(12,000,000)

^[1]

(18,000,000)

^[2]

Derivative Asset

97,000,000

131,000,000

Liabilities [Abstract]

Derivative Liability

13,000,000

20,000,000

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

(51,000,000)

^[1]

(51,000,000)

^[1]

(82,000,000)

^[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

2,000,000

7,000,000

Liabilities [Abstract]

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

10,000,000

22,000,000

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

96,000,000

122,000,000

Liabilities [Abstract]

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

53,000,000

77,000,000

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

20,000,000

Liabilities [Abstract]

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

$ 1,000,000

$ 3,000,000

[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 $39 million 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 $64 million posted with the same counterparties.
[3]	CERC did not have significant Level 3 purchases or sales during either of the three or six months ended June 30, 2015 or 2014.
[4]	Amounts are included in Prepaid Expenses and Other Current Assets in the Condensed Consolidated Balance Sheets.

Unconsolidated Affiliates Description (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2015

Jun. 30, 2014

Jun. 30, 2015

Jun. 30, 2014

Jul. 31, 2015

Dec. 31, 2014

May 30, 2014

Mar. 31, 2014

Accounts and notes receivable — affiliated companies

$ 14

$ 18

Publicly Traded Common Units, Percentage of Total Outstanding Units

7.00%

Investment in unconsolidated affiliates

$ 4,471

4,521

Enable Midstream Partners [Member]

Enable's common unit price

$ 15.98

Enable Midstream Partners [Member]

Equity Method Investment, Ownership Percentage

55.40%

Carrying value per unit of investment in Enable

$ 19.12

Amount below carrying value

$ 734

Investment in unconsolidated affiliates

$ 4,471

4,520

Southeast Supply Header LLC [Member]

Equity Method Investment, Ownership Percentage

25.05%

Equity Method Investment, Contributed Ownership Percentage

0.10%

24.95%

Investment in unconsolidated affiliates

^[1]

$ 0

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

Equity Method Investment, Ownership, Shares

139,704,916

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

Equity Method Investment, Ownership, Shares

94,151,707

Enable Guaranteed Senior Notes [Member]

Guarantee of Affiliate Senior Notes

$ 1,100

Enable Midstream Partners [Member]

Interest Income, Related Party

$ 2

$ 4

Due from Affiliate, Noncurrent

363

$ 363

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

2.10%

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

2.45%

Accounts and notes receivable — affiliated companies

$ 5

Enable Midstream Partners [Member] | Enable Guaranteed Senior Notes [Member]

Guarantee of Affiliate Senior Notes

1,100

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

Reimbursement Revenue

Accounts Receivable, Related Parties

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

Affiliate Costs

$ 27

$ 75

Accounts Payable, Related Parties, Current

$ 7

$ 23

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

Enable's common unit price

$ 16.36

Amount below carrying value

$ 645

[1]	CERC disposed of its remaining interest in SESH on June 30, 2015.

Unconsolidated Affiliates Financial Data(Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2015

Jun. 30, 2014

Jun. 30, 2015

Jun. 30, 2014

Dec. 31, 2014

Investment in unconsolidated affiliates

$ 4,471

$ 4,521

Equity in earnings of unconsolidated affiliates, net

$ 71

$ 162

CERC’s ownership interest in Enable partners’ capital

4,817

4,869

CERC’s basis difference attributable to goodwill (1)

^[1]

(217)

Equity Method Investment_Basis Difference To Be Accreted

^[2]

(129)

(132)

CERC’s total basis difference

(346)

(349)

CERC's investment in Enable

4,471

4,520

Proceeds from Equity Method Investment, Dividends or Distributions

145

164

Enable Midstream Partners [Member]

Investment in unconsolidated affiliates

4,471

4,520

Equity in earnings of unconsolidated affiliates, net

157

Operating revenues

590

826

1,206

1,828

Cost of sales, excluding depreciation and amortization

277

478

569

1,111

Operating income

139

197

301

Net income attributable to Enable

120

168

269

Grossequityinearnings

154

Basis difference accretion

CERC’s equity in earnings, net

157

Current assets

414

438

Non-current assets

11,766

11,399

Current liabilities

834

671

Non-current liabilities

2,611

2,343

Non-controlling interest

Enable partners’ capital

8,704

8,792

Proceeds from Equity Method Investment, Dividends or Distributions

145

157

Southeast Supply Header LLC [Member]

Investment in unconsolidated affiliates

^[3]

$ 1

Equity in earnings of unconsolidated affiliates, net

^[3]

Proceeds from Equity Method Investment, Dividends or Distributions

^[3]

$ 0

$ 4

$ 0

$ 7

[1]	The difference relates to CERC’s proportionate share of Enable’s goodwill arising from its acquisition of Enogex LLC, and therefore will be recognized by CERC upon dilution or disposition of its interest in Enable.
[2]	The difference will be recognized by CERC over 30 years beginning May 1, 2013. CERC will also adjust the accretable basis difference for dilution or disposition of its interest in Enable.
[3]	CERC disposed of its remaining interest in SESH on June 30, 2015.

Goodwill Goodwill (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Goodwill [Line Items]
Goodwill	$ 840	$ 840
Natural Gas Distribution
Goodwill [Line Items]
Goodwill	746	746
Energy Services
Goodwill [Line Items]
Goodwill	83	83
Other Operations
Goodwill [Line Items]
Goodwill	$ 11	$ 11

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Money Pool Borrowings	$ 0		$ 0		$ 188
Corporate service charges, related party	$ 31	$ 31	$ 59	$ 59

Short-term Borrowings and Long-term Debt (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Short-term Debt	$ 24	$ 53
Line of Credit Facility, Maximum Borrowing Capacity	600	600
Product Financing Arrangement [Member]
Short-term Debt	24	53
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	$ 72	$ 341
London Interbank Offered Rate (LIBOR) [Member] \| Line of Credit [Member]
Debt Instrument, Basis Spread on Variable Rate	1.50%

Commitments and Contingencies (Details) $ in Millions	6 Months Ended
Commitments and Contingencies (Details) $ in Millions	Jun. 30, 2015 USD ($)
Natural Gas Supply Commitments [Member]
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]
2015	$ 228
2016	485
2017	471
2018	419
2019	227
After 2019	$ 130
Gas Market Manipulation Cases [Member]
Recorded Unconditional Purchase Obligation Payment Schedule [Abstract]
Loss Contingency Pending Natural Gas Measurement Lawsuits Number	1
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	$ 7
Site Contingency Sites With Liability	5
Minnesota Service Territory [Member] \| Maximum [Member]
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract
Site Contingency, Loss Exposure Not Accrued, Low Estimate	$ 28
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	$ 4
Minimum years of remediation for the Minnesota sites (in years)	30
GenOn Demand Charges Transportation Contracts [Member]
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract
Guarantee of Affiliate Senior Notes	$ 36
Enable Guaranteed Senior Notes [Member]
LegalEnvironmentalAndOtherRegulatoryMattersLegalMattersGasMarketManipulationCasesAbstract
Guarantee of Affiliate Senior Notes	$ 1,100

Income Taxes (Details)	3 Months Ended		6 Months Ended
Income Taxes (Details)	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Effective Income Tax Rate	35.00%	38.00%	39.00%	38.00%

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

3 Months Ended

6 Months Ended

Jun. 30, 2015

Jun. 30, 2014

Jun. 30, 2015

Jun. 30, 2014

Dec. 31, 2014

Segment Reporting Information [Line Items]

Revenues

$ 824

$ 1,183

$ 2,641

$ 3,714

Operating Income (Loss)

187

227

Assets

10,501

$ 11,045

Equity in earnings of unconsolidated affiliates, net

162

Investment in unconsolidated affiliates

4,471

4,521

Natural Gas Distribution

Segment Reporting Information [Line Items]

Revenues

420

526

1,605

2,004

Operating Income (Loss)

165

192

Energy Services

Segment Reporting Information [Line Items]

Revenues

404

657

1,036

1,709

Operating Income (Loss)

Midstream Investments (1)

Segment Reporting Information [Line Items]

Revenues

^[1]

Operating Income (Loss)

^[1]

Other Operations

Segment Reporting Information [Line Items]

Revenues

Operating Income (Loss)

(1)

(2)

Intersegment Eliminations

Segment Reporting Information [Line Items]

Revenues

(11)

(25)

(37)

(66)

Assets

(823)

(964)

Intersegment Eliminations | Natural Gas Distribution

Segment Reporting Information [Line Items]

Revenues

(7)

(6)

(15)

Intersegment Eliminations | Energy Services

Segment Reporting Information [Line Items]

Revenues

(4)

(19)

(22)

(51)

Intersegment Eliminations | Midstream Investments (1)

Segment Reporting Information [Line Items]

Revenues

^[1]

Intersegment Eliminations | Other Operations

Segment Reporting Information [Line Items]

Revenues

Operating Segments [Member] | Natural Gas Distribution

Segment Reporting Information [Line Items]

Assets

5,301

5,464

Operating Segments [Member] | Energy Services

Segment Reporting Information [Line Items]

Assets

837

978

Operating Segments [Member] | Midstream Investments (1)

Segment Reporting Information [Line Items]

Assets

^[1]

4,471

4,521

Operating Segments [Member] | Other Operations

Segment Reporting Information [Line Items]

Assets

715

1,046

Southeast Supply Header LLC [Member]

Segment Reporting Information [Line Items]

Equity in earnings of unconsolidated affiliates, net

^[2]

Investment in unconsolidated affiliates

^[2]

Southeast Supply Header LLC [Member] | Midstream Investments (1)

Segment Reporting Information [Line Items]

Equity in earnings of unconsolidated affiliates, net

Investment in unconsolidated affiliates

Enable Midstream Partners [Member]

Segment Reporting Information [Line Items]

Equity in earnings of unconsolidated affiliates, net

157

Investment in unconsolidated affiliates

4,471

4,520

Enable Midstream Partners [Member] | Midstream Investments (1)

Segment Reporting Information [Line Items]

Equity in earnings of unconsolidated affiliates, net

$ 69

$ 157

Investment in unconsolidated affiliates

$ 4,471

$ 4,520

[1]	Midstream Investments’ equity earnings are as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 (in millions)Enable $43 $69 $95 $157SESH — 2 — 5 Total $43 $71 $95 $162Midstream Investments’ total assets are as follows: June 30, 2015 December 31, 2014 (in millions)Enable $4,471 $4,520SESH — 1 Total $4,471 $4,521
[2]	CERC disposed of its remaining interest in SESH on June 30, 2015.

Other Current Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Margin Deposits	$ 19	$ 19
Under Recovered Gas Costs	4	45
Over Recovered Gas Costs	$ 89	$ 37

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		6 Months Ended
	Jul. 22, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Subsequent Event [Line Items]
Proceeds from Equity Method Investment, Dividends or Distributions		$ 73	$ 94	$ 145	$ 164
Enable Midstream Partners [Member]
Subsequent Event [Line Items]
Proceeds from Equity Method Investment, Dividends or Distributions		$ 73	$ 90	$ 145	$ 157
Enable Midstream Partners [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Dividends Payable, Date Declared	Jul. 22, 2015
Common Stock, Dividends, Per Share, Declared	$ 0.316
Proceeds from Equity Method Investment, Dividends or Distributions	$ 74