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DEI Document - shares	3 Months Ended
DEI Document - shares	Mar. 31, 2015	Apr. 17, 2015
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Entity Registrant Name	Enable Midstream Partners, LP
Entity Central Index Key	0001591763
Entity Filer Category	Non-accelerated Filer
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		214,423,917

Condensed Consolidated Statements of Income (Unaudited) - USD ($)
shares in Millions, $ in Millions

3 Months Ended

Mar. 31, 2015

Mar. 31, 2014

Revenues (including revenues from affiliates (Note 11))

$ 616

$ 1,002

Cost of Goods Sold, excluding depreciation and amortization (including expenses from affiliates (Note 11))

292

633

Operating Expenses:

Operation and maintenance (including expenses from affiliates (Note 11))

130

126

Depreciation and amortization

Taxes other than income taxes

Total Operating Expenses

220

207

Operating Income

104

162

Other Income (Expense):

Interest expense (including expenses from affiliates (Note 11))

(20)

(14)

Equity in earnings of equity method affiliates

Other, net

Total Other Income (Expense)

(12)

(11)

Income Before Income Taxes

151

Income tax expense (benefit)

Net Income

150

Less: Net income attributable to noncontrolling interest

Net Income attributable to Enable Midstream Partners, LP

149

Net Income (Loss) Allocated to Limited Partners

$ 91

$ 149

Basic and diluted weighted average number of outstanding limited partner units (in units)

422

390

Common Units

Other Income (Expense):

Net Income (Loss) Allocated to Limited Partners

$ 48

$ 149

Basic and diluted earnings per unit (Note 4) (in dollars per unit)

$ 0.22

$ 0.38

Basic and diluted weighted average number of outstanding limited partner units (in units)

214

390

Subordinated Units

Other Income (Expense):

Net Income (Loss) Allocated to Limited Partners

$ 43

$ 0

Basic and diluted earnings per unit (Note 4) (in dollars per unit)

^[1]

$ 0.21

$ 0.00

Basic and diluted weighted average number of outstanding limited partner units (in units)

^[1]

208

[1]	Basic and diluted earnings per subordinated unit reflect net income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Net income	$ 91	$ 150
Comprehensive income	91	150
Less: Comprehensive income attributable to noncontrolling interest	0	1
Comprehensive income attributable to Enable Midstream Partners, LP	$ 91	$ 149

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents	$ 8	$ 12
Accounts receivable	252	254
Accounts receivable—affiliated companies	29	27
Inventory	50	63
Gas imbalances	37	45
Other current assets	31	37
Total current assets	407	438
Property, Plant and Equipment:
Property, plant and equipment	10,695	10,464
Less accumulated depreciation and amortization	948	882
Property, plant and equipment, net	9,747	9,582
Other Assets:
Intangible assets, net	350	357
Goodwill	1,068	1,068
Investment in equity method affiliates	349	348
Other	47	44
Total other assets	1,814	1,817
Total Assets	11,968	11,837
Current Liabilities:
Accounts payable	287	275
Accounts payable—affiliated companies	17	38
Short-term debt	436	253
Taxes accrued	26	23
Gas imbalances	8	13
Other	67	69
Total current liabilities	841	671
Other Liabilities:
Accumulated deferred income taxes, net	10	9
Notes payable—affiliated companies	363	363
Regulatory liabilities	17	16
Other	24	27
Total other liabilities	414	415
Long-Term Debt	1,926	1,928
Commitments and Contingencies (Note 12)
Common Unit, Issuance Value	4,338	4,353
Subordinated Unit, Issuance Value	4,418	4,439
Partners’ Capital:
Total partners' capital attributable to Enable Midstream Partners, LP Partners’ Capital	8,756	8,792
Noncontrolling interest	31	31
Total Partners’ Capital	8,787	8,823
Total Liabilities and Partners’ Capital	$ 11,968	$ 11,837

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Cash Flows from Operating Activities:
Net income	$ 91	$ 150
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	73	67
Equity in earnings of equity method affiliates, net of distributions	5	0
Equity based compensation	3	0
Amortization of debt costs and discount (premium)	(1)	(3)
Changes in other assets and liabilities:
Accounts receivable, net	2	(59)
Accounts receivable—affiliated companies	(2)	7
Inventory	13	19
Gas imbalance assets	8	(15)
Other current assets	6	1
Other assets	(2)	(9)
Accounts payable	18	(61)
Accounts payable—affiliated companies	(21)	0
Gas imbalance liabilities	(5)	9
Other current liabilities	2	(5)
Other liabilities	(2)	5
Net cash provided by operating activities	188	106
Cash Flows from Investing Activities:
Capital expenditures	(239)	(149)
Investment in equity method affiliates	(6)	0
Net cash provided by (used in) investing activities	(245)	(149)
Cash Flows from Financing Activities:
Proceeds from revolving credit facility	0	115
Repayment of revolving credit facility	0	(487)
Increase in short term debt	183	433
Distributions to partners	(130)	(114)
Net cash provided by (used in) financing activities	53	(53)
Net Increase in Cash and Cash Equivalents	(4)	(96)
Cash and Cash Equivalents at Beginning of Period	12	108
Cash and Cash Equivalents at End of Period	$ 8	$ 12

Condensed Consolidated Statements of Enable Midstream Partners, LP Partners' Capital (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Total Enable Midstream Partners, LP Partners’ Capital	Noncontrolling Interest	Subordinated Units Partners' Capital	Common Units Partners' Capital
Balance, beginning of period at Dec. 31, 2013	$ 8,181	$ 8,148	$ 33	$ 0	$ 8,148
Balance, beginning of period, units at Dec. 31, 2013				0	390
Changes in Partners' Capital
Net income	150	149	1	$ 0	$ 149
Distributions to partners	(114)	(114)	0	$ 0	$ (114)
Equity based compensation	0
Balance, end of period, units at Mar. 31, 2014				0	390
Balance, end of period at Mar. 31, 2014	8,217	8,183	34	$ 0	$ 8,183
Balance, beginning of period at Dec. 31, 2014	8,823	8,792	31	$ 4,439	$ 4,353
Balance, beginning of period, units at Dec. 31, 2014				208	214
Changes in Partners' Capital
Net income	91	91	0	$ 43	$ 48
Distributions to partners	(130)	(130)	0	$ (64)	$ (66)
Equity based compensation, units					0
Equity based compensation	3	3	0		$ 3
Balance, end of period, units at Mar. 31, 2015				208	214
Balance, end of period at Mar. 31, 2015	$ 8,787	$ 8,756	$ 31	$ 4,418	$ 4,338

Summary of Significant Accounting Policies	3 Months Ended
Summary of Significant Accounting Policies	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Organization Enable Midstream Partners, LP (Partnership) is a Delaware limited partnership formed on May 1, 2013 by CenterPoint Energy, Inc. (CenterPoint Energy), OGE Energy Corp. (OGE Energy) and affiliates of ArcLight Capital Partners, LLC (ArcLight), pursuant to the terms of the MFA. The Partnership is a large-scale, growth-oriented limited partnership formed to own, operate and develop strategically located natural gas and crude oil infrastructure assets. The Partnership’s assets and operations are organized into two reportable segments: (i) Gathering and Processing, which primarily provides natural gas gathering, processing and fractionation services and crude oil gathering for our producer customers, and (ii) Transportation and Storage, which provides interstate and intrastate natural gas pipeline transportation and storage service primarily to natural gas producers, utilities and industrial customers. The natural gas gathering and processing assets are located in five states and serve natural gas production in the Anadarko, Arkoma and Tex-La basins. This segment also includes a crude oil gathering business in the Bakken Shale formation, principally located in the Williston basin. The natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois. The Partnership is controlled equally by CenterPoint Energy and OGE Energy, who each have 50% of the management rights of Enable GP. Enable GP was established by CenterPoint Energy and OGE Energy to govern the Partnership and has no other operating activities. Enable GP is governed by a board made up of an equal number of representatives designated by each of CenterPoint Energy and OGE Energy, along with the Partnership's Chief Executive Officer and the independent board members CenterPoint Energy and OGE Energy mutually agreed to appoint. Based on the 50/50 management ownership, with neither company having control, CenterPoint Energy and OGE Energy do not consolidate their interests in the Partnership. CenterPoint Energy and OGE Energy also own a 40% and 60% interest, respectively, in the incentive distribution rights held by Enable GP. At March 31, 2015, CenterPoint Energy held approximately 55.4% of the limited partner interests in the Partnership, or 94,126,366 common units and 139,704,916 subordinated units, and OGE Energy held approximately 26.3% of the limited partner interests in the Partnership, or 42,832,291 common units and 68,150,514 subordinated units. For the period from December 31, 2013 through May 29, 2014, the financial statements reflect a 24.95% interest in SESH. For the period of May 30, 2014 through March 31, 2015, the financial statements reflect a 49.90% interest in SESH. See Note 6 for further discussion of SESH. On April 16, 2014, the Partnership completed the Offering of 25,000,000 common units, representing limited partner interests in the Partnership, at a price to the public of $20.00 per common unit. The Partnership received net proceeds of $464 million from the sale of the common units, after deducting underwriting discounts and commissions, the structuring fee and offering expenses. In connection with the Offering, underwriters exercised their option to purchase 3,750,000 additional common units, which were fulfilled with units held by ArcLight. As a result, the Partnership did not receive any proceeds from the sale of common units pursuant to the exercise of the underwriters' option to purchase additional common units. The exercise of the underwriters' option to purchase additional common units did not affect the total number of units outstanding or the amount of cash needed to pay the minimum quarterly distribution on all outstanding units. The Partnership retained the net proceeds of the Offering for general partnership purposes, including the funding of expansion capital expenditures, and to pre-fund demand fees expected to be incurred over the next three years relating to certain expiring transportation and storage contracts. In connection with the Offering, 139,704,916 of CenterPoint Energy's common units and 68,150,514 of OGE Energy's common units were converted into subordinated units. Basis of Presentation The accompanying condensed consolidated financial statements and related notes of the Partnership have been prepared pursuant to the rules and regulations of the SEC and GAAP. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with GAAP have been omitted. The accompanying condensed consolidated financial statements and related notes should be read in conjunction with the combined and consolidated financial statements and related notes included in our Annual Report. These condensed consolidated financial statements and the related financial statement disclosures reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position and results of operations for the respective periods. Amounts reported in the Partnership’s Condensed Consolidated Statements of 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 the Partnership’s reportable business segments, see Note 14. Use of Estimates The preparation of financial statements in conformity with GAAP 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. Income Taxes As a limited partnership, the Partnership’s earnings are no longer subject to income tax (other than Texas state margin taxes and taxes associated with the Partnership's corporate subsidiary) and are taxable at the individual partner level, with the exception of Enable Midstream Services, LLC, a wholly owned subsidiary (Enable Midstream Services). The Partnership and its subsidiaries are pass-through entities for federal income tax purposes. For these entities, all income, expenses, gains, losses and tax credits generated flow through to their owners and, accordingly, do not result in a provision for income taxes in the consolidated financial statements. Reverse Unit Split On March 25, 2014, the Partnership effected a 1 for 1.279082616 reverse unit split. All unit and per unit amounts presented within the condensed consolidated financial statements reflect the effects of the reverse unit split. Second Amended and Restated Agreement of Limited Partnership of Enable Midstream Partners, LP On April 16, 2014, in connection with the closing of the Offering of the Partnership, the Partnership amended and restated its First Amended and Restated Agreement of Limited Partnership to remove certain provisions that expired upon completion of the Offering. Following the Offering, ArcLight no longer has protective approval rights over certain material activities of the Partnership, including material increases in capital expenditures and certain equity issuances, entering into transactions with related parties and acquiring, pledging or disposing of certain material assets.

New Accounting Pronouncements	3 Months Ended
New Accounting Pronouncements	Mar. 31, 2015
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements Revenue from Contracts with Customers In May 2014, FASB issued ASU No. 2014-09, "Revenue from Contracts with Customers," which supersedes the revenue recognition requirements in "Revenue Recognition (Topic 605)," and requires entities to recognize revenue in a way that depicts the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods or services. ASU 2014-09 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, and is to be applied retrospectively, with early application not permitted. On April 1, 2015, FASB proposed deferring the effective date of ASU 2014-09 by one year to December 15, 2017 for annual reporting periods beginning after that date. The FASB also proposed permitting early adoption of the standard, but not before the original effective date of December 15, 2016. The Partnership is currently evaluating the impact, if any, the adoption of this standard will have on our Consolidated Financial Statements. Consolidation In February 2015, FASB issued ASU No. 2015-02, “Consolidation,” to improve consolidation guidance for certain types of legal entities. The guidance modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, eliminates the presumption that a general partner should consolidate a limited partnership, affects the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships, and provides a scope exception from consolidation guidance for certain money market funds. These provisions are effective for annual reporting periods beginning after December 15, 2015, and interim periods within those annual periods, with early adoption permitted. These provisions may also be adopted retrospectively in previously issued financial statements for one or more years with a cumulative-effect adjustment to partners’ capital as of the beginning of the first year restated. The Partnership is currently evaluating the effect that adopting this new accounting standard will have on our Consolidated Financial Statements and related disclosures. Presentation of Debt Issuance Costs In April 2015, FASB issued ASU No. 2015-03, "Simplifying the Presentation of Debt Issuance Costs." This standard amends existing guidance to require the presentation of debt issuance costs in the balance sheet as a deduction from the carrying amount of the related debt liability instead of a deferred charge. It is effective for annual reporting periods beginning after December 15, 2015, but early adoption is permitted. The Partnership is currently evaluating the impact the adoption of this standard will have on our Consolidated Financial Statements and related disclosures. Customer's Accounting for Fees Paid in a Cloud Computing Arrangement In April 2015, the FASB issued ASU No. 2015-05, "Customer's Accounting for Fees Paid in a Cloud Computing Arrangement." This standard 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 new guidance does not change the accounting for a customer's accounting for service contracts. ASU No. 2015-05 is effective for interim and annual reporting periods beginning after December 15, 2015. The Partnership is currently evaluating the impact, if any, of the adoption of this standard will have on our Consolidated Financial Statements.

- Definition

The entire disclosure of changes in accounting principles, including adoption of new accounting pronouncements, that describes the new methods, amount and effects on financial statement line items.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6507316

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Direct Effects of a Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6510796

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22583-107794

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Indirect Effects of a Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6515603

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22580-107794

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.10-01.(b)(6))
-URI http://asc.fasb.org/extlink&oid=27015980&loc=d3e46468-122699

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Accounting Change
-URI http://asc.fasb.org/extlink&oid=6503790

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22499-107794

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Retrospective Application
-URI http://asc.fasb.org/extlink&oid=6523989

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section 45
-Paragraph 13
-URI http://asc.fasb.org/extlink&oid=6372559&loc=d3e765-108305

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section 45
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6372559&loc=d3e725-108305

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 01
-Paragraph b
-Subparagraph 6
-Article 10

+ Details

Earnings Per Liminted Partner Unit

3 Months Ended

Mar. 31, 2015

Earnings Per Share [Abstract]

Earnings Per Limited Partner Unit

The following table illustrates the Partnership’s calculation of earnings per unit for common and subordinated limited partner units:



	Three Months Ended March 31,
	2015		2014
	(In millions, except per unit data)
Net income attributable to Enable Midstream Partners, LP	$	91	$	149
Less general partner interest in net income	—		—
Limited partner interest in net income attributable to Enable Midstream Partners, LP	$	91	$	149
Net income allocable to common units	$	48	$	149
Net income allocable to subordinated units	43		—
Limited partner interest in net income attributable to Enable Midstream Partners, LP	$	91	$	149
Basic and diluted weighted average number of outstanding limited partner units
Common units	214		390
Subordinated units⁽¹⁾	208		—
Total	422		390
Basic and diluted earnings per limited partner unit
Common units	$	0.22	$	0.38
Subordinated units⁽¹⁾	$	0.21	$	—

____________________


(1)	Basic and diluted earnings per subordinated unit reflect net income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

There was no dilutive effect of unit-based awards during the three months ended March 31, 2015.

Enable Midstream Partners, LP Partners' Capital

3 Months Ended

Mar. 31, 2015

Equity [Abstract]

Enable Midstream Partners, LP Parent Net Equity and Partners' Capital

Partners’ Capital

In accordance with the Partnership’s First Amended and Restated Agreement of Limited Partnership, on February 14, 2014, May 14, 2014 and August 14, 2014, the Partnership distributed $114 million, $155 million and $22 million to the unitholders of record as of January 1, 2014, April 1, 2014, and April 1, 2014, respectively.

The Partnership's Second Amended and Restated Agreement of Limited Partnership requires that, within 45 days subsequent to the end of each quarter, the Partnership distribute all of its available cash (as defined in the Second Amended and Restated Agreement of Limited Partnership) to unitholders of record on the applicable record date. The Partnership did not make distributions for the period that began on April 1, 2014 and ended on April 15, 2014, the day prior to the closing of the Offering, other than the required distributions to CenterPoint Energy, OGE Energy, and ArcLight under the First Amended and Restated Agreement of Limited Partnership.

The Partnership paid or has authorized payment of the following cash distributions under the Second Amended and Restated Agreement of Limited Partnership during 2014 and 2015 (in millions, except for per unit amounts):



Quarter Ended	Record Date	Payment Date	Per Unit Distribution		Total Cash Distribution
March 31, 2015⁽¹⁾	May 5, 2015	May 15, 2015	$	0.3125	$	132
December 31, 2014	February 4, 2015	February 13, 2015	$	0.30875	$	130
September 30, 2014	November 4, 2014	November 14, 2014	$	0.3025	$	128
June 30, 2014 ⁽²⁾	August 4, 2014	August 14, 2014	$	0.2464	$	104

_____________________


(1)	The board of directors of Enable GP declared this $0.3125 per common unit cash distribution on April 24, 2015, to be paid on May 15, 2015, to unitholders of record at the close of business on May 5, 2015.


(2)	The quarterly distribution for three months ended June 30, 2014 was prorated for the period beginning immediately after the closing of the Partnership's Offering, April 16, 2014 through June 30, 2014.

General Partner Interest and Incentive Distribution Rights

Enable GP owns a non-economic general partner interest in the Partnership and thus will not be entitled to distributions that the Partnership makes prior to the liquidation of the Partnership in respect of such general partner interest. Enable GP currently holds incentive distribution rights that entitle it to receive increasing percentages, up to a maximum of 50.0%, of the cash the Partnership distributes from operating surplus (as defined in our partnership agreement) in excess of $0.330625 per unit per quarter. The maximum distribution of 50.0% does not include any distributions that Enable GP or its affiliates may receive on common units or subordinated units that they own.

Subordinated Units

All subordinated units are held by CenterPoint Energy and OGE Energy. These units are considered subordinated because during the subordination period (as defined in our partnership agreement), the common units will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.2875 per common unit, which amount is defined in the partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions until the common units have received the minimum quarterly distribution plus any arrearages from prior quarters. Furthermore, no arrearages will be paid on the subordinated units.

Subordination Period

The subordination period began on the closing date of the Offering and will extend until the first business day following the distributions of available cash from operating surplus (as defined in the partnership agreement) on each of the outstanding common units and subordinated units equal to or exceeding $1.15 per unit (the annualized minimum quarterly distribution) for each of the three consecutive, non-overlapping four-quarter periods immediately preceding June 30, 2017. Also, if the Partnership has paid distributions of available cash from operating surplus on each of the outstanding common units and subordinated units equal to or exceeding $1.725 per unit (150% of the annualized minimum quarterly distribution) and the related distribution on the incentive distribution rights, for any four-consecutive-quarter period ending on or after June 30, 2015, the subordination period will terminate.

Intangible Assets, Net

3 Months Ended

Mar. 31, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Intangible Assets, Net

The Partnership has $401 million in intangible assets associated with customer relationships due to the acquisition of Enogex. The Partnership determined that intangible assets related to customer relationships have a weighted average useful life of 15 years as of May 1, 2013. Intangible assets do not have any significant residual value or renewal options of existing terms. There are no intangible assets with indefinite useful lives.

Intangible assets consist of the following:



	March 31, 2015		December 31, 2014
	(In millions)
Customer relationships:
Total intangible assets	$	401	$	401
Accumulated amortization	51		45
Net intangible assets	$	350	$	356

The Partnership recorded amortization expense of $6 million and $7 million during each of the three months ended March 31, 2015 and 2014, respectively.

Investment in Equity Method Affiliates

3 Months Ended

Mar. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Investments in Equity Method Affiliates

The Partnership uses the equity method of accounting for investments in entities in which it has an ownership interest between 20% and 50% and exercises significant influence.

For the period from May 1, 2013 through May 29, 2014, the Partnership held a 24.95% interest in SESH, which is accounted for as an investment in equity method affiliates, and CenterPoint Energy indirectly owned a 25.05% interest in SESH. Pursuant to the MFA, that interest could be contributed to the Partnership upon exercise of certain put or call rights, under which CenterPoint Energy would contribute to the Partnership CenterPoint Energy’s retained interest in SESH at a price equal to the fair market value of such interest at the time the put right or call right is exercised. On May 13, 2014, CenterPoint Energy exercised its put right with respect to a 24.95% interest in SESH. Pursuant to the put right, on May 30, 2014, CenterPoint Energy contributed a 24.95% interest in SESH to the Partnership in exchange for 6,322,457 common units representing limited partner interests in the Partnership, which had a fair value of $161 million based upon the closing market price of the Partnership's common units. If CenterPoint Energy were to exercise its remaining put right or the Partnership were to exercise its remaining call right (which may be no earlier than June 2015), CenterPoint Energy’s retained interest in SESH would be contributed to the Partnership in exchange for consideration consisting of 25,341 limited partner units for a 0.1% interest in SESH and, subject to certain restrictions, a cash payment, payable either from CenterPoint Energy to the Partnership or from the Partnership to CenterPoint Energy, in an amount such that the total consideration exchanged is equal in value to the fair market value of the contributed interest in SESH, subject to adjustment for accretion and dilution events. Affiliates of Spectra Energy Corp own the remaining 50% interest in SESH. Pursuant to the terms of the SESH LLC Agreement, if, at any time, CenterPoint Energy has a right to receive less than 50% of our distributions through its limited partner interest in the Partnership and its economic interest in Enable GP, affiliates of Spectra Energy Corp will have the right to purchase our interest in SESH at fair market value. As of March 31, 2015, the Partnership owned a 49.90% interest in SESH.

In connection with CenterPoint Energy's exercise of its put right with respect to its 24.95% interest in SESH, the parties agreed to allocate the distributions for the quarter ended June 30, 2014 on (i) the SESH interest acquired by Enable and (ii) the Enable units issued to CenterPoint Energy for the SESH interest pro rata based on the time each party held the relevant interest. On July 25, 2014, the Partnership received a $7 million distribution from SESH for the three month period ended June 30, 2014, representing the Partnership's 49.90% interest in SESH. Under the terms of the agreement, the Partnership made a payment of approximately $1 million to CenterPoint Energy related to the additional 24.95% interest during the quarter ending September 30, 2014.

Investment in Equity Method Affiliates:



	Three Months Ended March 31,
	2015			2014
	(In millions)
Balance as of December 31	$	348		$	198
Equity in earnings of equity method affiliate	7			3
Contributions to equity method affiliate	6			—
Distributions from equity method affiliate	(12		)	(3		)
Balance as of March 31	$	349		$	198

Equity in Earnings of Equity Method Affiliates:



	Three Months Ended March 31,
	2015		2014
	(In millions)
SESH	$	7	$	3

Distributions from Equity Method Affiliates:



	Three Months Ended March 31,
	2015		2014
	(In millions)
SESH	$	12	$	3

Summarized financial information of SESH is presented below:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Income Statements:
Revenues	$	29	$	27
Operating income	18		17
Net income	14		12

Debt

3 Months Ended

Mar. 31, 2015

Debt Disclosure [Abstract]

Debt

The following table presents the Partnership's outstanding debt as of March 31, 2015 and December 31, 2014.



	March 31, 2015		December 31, 2014
	(In millions)
Commercial Paper	$	436	$	253
Notes payable — affiliated companies	363		363
2019 Notes	500		500
2024 Notes	600		600
2044 Notes	550		550
Enable Oklahoma Senior Notes	250		250
Premium (Discount) on long-term debt	26		28
Total debt	2,725		2,544
Less amount classified as short-term debt⁽¹⁾	436		253
Less Notes payable—affiliated companies	363		363
Total long-term debt	$	1,926	$	1,928

___________________


(1)	Short-term debt includes $436 million and $253 million of commercial paper as of March 31, 2015 and December 31, 2014, respectively.

Revolving Credit Facility

The Partnership has a $1.4 billion senior unsecured revolving credit facility (Revolving Credit Facility) that is scheduled to expire on May 1, 2018. As of March 31, 2015 there were no principal advances and $2 million in letters of credit outstanding under the Revolving Credit Facility. However, as discussed below, commercial paper borrowings effectively reduce our borrowing capacity under this Revolving Credit Facility.

Commercial Paper

The Partnership has a commercial paper program, pursuant to which the Partnership is authorized to issue up to $1.4 billion of commercial paper. The commercial paper program is supported by our Revolving Credit Facility, and outstanding commercial paper effectively reduces our borrowing capacity thereunder. As of March 31, 2015, $436 million was outstanding under our commercial paper program. Any reduction in our credit ratings could prevent us from accessing the commercial paper markets.

Financing Costs

Unamortized debt expense of $16 million and $17 million as of March 31, 2015 and December 31, 2014, respectively, is classified in Other Assets in the Condensed Consolidated Balance Sheets and is being amortized over the life of the respective debt. Unamortized premium on long-term debt of $26 million and $28 million at March 31, 2015 and December 31, 2014, respectively, is classified as either Long-Term Debt or Current Portion of Long-Term Debt, consistent with the underlying debt instrument, in the Condensed Consolidated Balance Sheets and is being amortized over the life of the respective debt.

As of March 31, 2015, the Partnership and Enable Oklahoma were in compliance with all of their debt agreements, including financial covenants.

Fair Value Measurements

3 Months Ended

Mar. 31, 2015

Fair Value Disclosures [Abstract]

Fair Value Measurements

Certain assets and liabilities are recorded at fair value in the Condensed Consolidated Balance Sheets and 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. Instruments classified as Level 1 include natural gas futures, swaps and options transactions for contracts traded on the NYMEX and settled through a NYMEX clearing broker.

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. Instruments classified as Level 2 include over-the-counter NYMEX natural gas swaps, natural gas basis swaps and natural gas purchase and sales transactions in markets such that the pricing is closely related to the NYMEX pricing, and over-the-counter WTI crude swaps for condensate sales.

Level 3: Inputs are unobservable for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. Unobservable inputs reflect the Partnership’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Partnership develops these inputs based on the best information available, including the Partnership’s own data.

The Partnership utilizes the market approach in determining the fair value of its derivative positions by using either NYMEX or WTI published market prices, independent broker pricing data or broker/dealer valuations. The valuations of derivatives with pricing based on NYMEX published market prices may be considered Level 1 if they are settled through a NYMEX clearing broker account with daily margining. Over-the-counter derivatives with NYMEX or WTI based prices are considered Level 2 due to the impact of counterparty credit risk. Valuations based on independent broker pricing or broker/dealer valuations may be classified as Level 2 only to the extent they may be validated by an additional source of independent market data for an identical or closely related active market. In certain less liquid markets or for longer-term contracts, forward prices are not as readily available. In these circumstances, contracts are valued using internally developed methodologies that consider historical relationships among various quoted prices in active markets that result in management’s best estimate of fair value. These contracts are classified as Level 3.

The Partnership 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 period ended March 31, 2015, there were no transfers between Level 1, 2, and 3 investments.

The impact to the fair value of derivatives due to credit risk is calculated using the probability of default based on Standard & Poor’s Ratings Services and/or internally generated ratings. The fair value of derivative assets is adjusted for credit risk. The fair value of derivative liabilities is adjusted for credit risk only if the impact is deemed material.

Contracts with Master Netting Arrangements

Fair value amounts recognized for forward, interest rate swap, option and other conditional or exchange contracts executed with the same counterparty under a master netting arrangement may be offset. The reporting entity’s choice to offset or not must be applied consistently. A master netting arrangement exists if the reporting entity has multiple contracts, whether for the same type of conditional or exchange contract or for different types of contracts, with a single counterparty that are subject to a contractual agreement that provides for the net settlement of all contracts through a single payment in a single currency in the event of default on or termination of any one contract. Offsetting the fair values recognized for forward, interest rate swap, option and other conditional or exchange contracts outstanding with a single counterparty results in the net fair value of the transactions being reported as an asset or a liability in the Condensed Consolidated Balance Sheets. The Partnership has presented the fair values of its derivative contracts under master netting agreements using a net fair value presentation.

The following tables summarize the Partnership’s assets and liabilities that are measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014:



March 31, 2015	Commodity Contracts						Gas Imbalances ⁽¹⁾
	Assets			Liabilities			Assets ⁽²⁾		Liabilities ⁽³⁾
	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	26		$	4		$	—	$	—
Significant other observable inputs (Level 2)	1			—			29		$	5
Unobservable inputs (Level 3)	7			—			—		$	—
Total fair value	34			4			29		$	5
Netting adjustments	(4		)	(4		)	—		$	—
Total	$	30		$	—		$	29	$	5



December 31, 2014	Commodity Contracts						Gas Imbalances ⁽¹⁾
	Assets			Liabilities			Assets ⁽²⁾		Liabilities ⁽³⁾
	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	33		$	4		$	—	$	—
Significant other observable inputs (Level 2)	2			—			40		12
Unobservable inputs (Level 3)	5			—			—		—
Total fair value	40			4			40		12
Netting adjustments	(4		)	(4		)	—		—
Total	$	36		$	—		$	40	$	12

______________________

(1)

The Partnership uses the market approach to fair value its gas imbalance assets and liabilities at individual, or where appropriate an average of, current market indices applicable to the Partnership’s operations, not to exceed net realizable value. Gas imbalances held by Enable Oklahoma are valued using an average of the Inside FERC Gas Market Report for Panhandle Eastern Pipe Line Co. (Texas, Oklahoma Mainline), ONEOK (Oklahoma) and ANR Pipeline (Oklahoma) indices. There were no netting adjustments as of March 31, 2015 and December 31, 2014.


(2)	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $8 million and $4 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.


(3)	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $1 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.

Estimated Fair Value of Financial Instruments

The fair values of all accounts receivable, notes receivable, accounts payable, notes payable-commercial paper, and other such financial instruments on the Condensed Consolidated Balance Sheets are estimated to be approximately equivalent to their carrying amounts and have been excluded from the table below. The following table summarizes the fair value and carrying amount of the Partnership’s financial instruments at March 31, 2015 and December 31, 2014.



	March 31, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)
Long-Term Debt
Long-term notes payable - affiliated companies (Level 2)	$	363	$	365	$	363	$	362
Revolving Credit Facility (Level 2)⁽¹⁾	—		—		—		—
Enable Oklahoma Senior Notes (Level 2)⁽²⁾	277		282		279		282
Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2)	1,649		1,568		1,649		1,592

___________________


(1)	Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $436 million and $253 million of commercial paper was outstanding as of March 31, 2015 and December 31, 2014, respectively.


(2)	No amount was included in short term debt as of March 31, 2015 and December 31, 2014, respectively.

The fair value of the Partnership’s Long-term notes payable—affiliated companies, along with the Enable Oklahoma Senior Notes and Enable Midstream Partners, LP 2019, 2024 and 2044 Notes, is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy.

Non-Financial Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances (e.g., when there is evidence of impairment).

As of March 31, 2015 and December 31, 2014, no material fair value adjustments or fair value measurements were required for these non-financial assets or liabilities.

- 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

Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

The Partnership is exposed to certain risks relating to its ongoing business operations. The primary risk managed using derivative instruments is commodity price risk. The Partnership is also exposed to credit risk in its business operations.

Commodity Price Risk

The Partnership has used forward physical contracts, commodity price swap contracts and commodity price option features to manage the Partnership’s commodity price risk exposures in the past. Commodity derivative instruments used by the Partnership are as follows:


•	NGL put options, NGL futures and swaps, and WTI crude futures and swaps for condensate sales are used to manage the Partnership’s NGL and condensate exposure associated with its processing agreements;


•	natural gas futures and swaps are used to manage the Partnership’s keep-whole natural gas exposure associated with its processing operations and the Partnership’s natural gas exposure associated with operating its gathering, transportation and storage assets; and


•	natural gas futures and swaps, natural gas options and natural gas commodity purchases and sales are used to manage the Partnership’s natural gas exposure associated with its storage and transportation contracts and asset management activities.

Normal purchases and normal sales contracts are not recorded in Other Assets or Liabilities in the Condensed Consolidated Balance Sheets and earnings are recognized and recorded in the period in which physical delivery of the commodity occurs. Management applies normal purchases and normal sales treatment to: (i) commodity contracts for the purchase and sale of natural gas used in or produced by the Partnership’s operations and (ii) commodity contracts for the purchase and sale of NGLs produced by the Partnership’s gathering and processing business.

The Partnership recognizes its non-exchange traded derivative instruments as Other Assets or Liabilities in the Condensed Consolidated Balance Sheets at fair value with such amounts classified as current or long-term based on their anticipated settlement. Exchange traded transactions are settled on a net basis daily through margin accounts with a clearing broker and, therefore, are recorded at fair value on a net basis in Other Current Assets in the Condensed Consolidated Balance Sheets.

As of March 31, 2015 and December 31, 2014, the Partnership had no derivative instruments that were designated as cash flow or fair value hedges for accounting purposes.

Credit Risk

The Partnership is exposed to certain credit risks relating to its ongoing business operations. Credit risk includes the risk that counterparties that owe the Partnership money or energy will breach their obligations. If the counterparties to these arrangements fail to perform, the Partnership may be forced to enter into alternative arrangements. In that event, the Partnership’s financial results could be adversely affected, and the Partnership could incur losses.

Derivatives Not Designated As Hedging Instruments

Derivative instruments not designated as hedging instruments for accounting purposes are utilized in the Partnership’s asset management activities. For derivative instruments not designated as hedging instruments, the gain or loss on the derivative is recognized currently in earnings.

Quantitative Disclosures Related to Derivative Instruments

The majority of natural gas physical purchases and sales not designated as hedges for accounting purposes are priced based on a monthly or daily index, and the fair value is subject to little or no market price risk. Natural gas physical sales volumes exceed natural gas physical purchase volumes due to the marketing of natural gas volumes purchased via the Partnership’s processing contracts, which are not derivative instruments.

As of March 31, 2015 and December 31, 2014, the Partnership had the following derivative instruments that were not designated as hedging instruments for accounting purposes:



	March 31, 2015		December 31, 2014
	Gross Notional Volume
	Purchases	Sales	Purchases	Sales
Natural gas—TBtu⁽¹⁾
Physical purchases/sales	5	67	4	32
Financial fixed futures/swaps	5	34	5	35
Financial basis futures/swaps	4	40	7	54
Condensate—MBbl⁽²⁾
Financial Futures/swaps	—	970	—	12
Natural gas liquids—MBbl⁽³⁾
Financial Futures/swaps	—	714	—	—

____________________

(1)

As of March 31, 2015, 93.5% of the natural gas contracts had durations of one year or less, 5.1% had durations of more than one year and less than two years and 1.4% had durations of more than two years. As of December 31, 2014, 91.2% of the natural gas contracts had durations of one year or less, 6.5% had durations of more than one year and less than two years and 2.2% had durations of more than two years.


(2)	As of March 31, 2015, 75.5% of the condensate contracts had durations of one year or less and 24.5% had durations of more than one year and less than two years. As of December 31, 2014, 100.0% of the condensate contracts had durations of one year or less.


(3)	As of March 31, 2015, 100.0% of the natural gas liquids contracts had durations of one year or less.

Balance Sheet Presentation Related to Derivative Instruments

The fair value of the derivative instruments that are presented in the Partnership’s Condensed Consolidated Balance Sheet as of March 31, 2015 and December 31, 2014 that were not designated as hedging instruments for accounting purposes are as follows:



		March 31, 2015				December 31, 2014
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
		(In millions)
Natural gas
Financial futures/swaps	Other Current	$	27	$	4	$	34	$	4
Physical purchases/sales	Other Current	1		—		1		—
Condensate
Financial futures/swaps	Other Current	6		—		5		—
Natural gas liquids
Financial Futures/swaps	Other Current	—		—		—		—
Total gross derivatives ⁽¹⁾		$	34	$	4	$	40	$	4

_____________________


(1)	See Note 8 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of March 31, 2015 and December 31, 2014.

Income Statement Presentation Related to Derivative Instruments

The following tables present the effect of derivative instruments on the Partnership’s Condensed Consolidated Statement of Income for the three months ended March 31, 2015.



	Amounts Recognized in Income
	Three Months Ended March 31,
	2015			2014
	(In millions)
Natural gas financial futures/swaps gains (losses)	$	7		$	2
Natural gas physical purchases/sales gains (losses)	(4		)	2
Condensate financial futures/swaps gains (losses)	4			—
Natural gas liquids financial futures/swaps gains (losses)	—			—
Total	$	7		$	4

For derivatives not designated as hedges in the tables above, amounts recognized in income for the periods ended March 31, 2015 and 2014, if any, are reported in Revenues.

Credit-Risk Related Contingent Features in Derivative Instruments

In the event Moody’s Investors Services or Standard & Poor’s Ratings Services were to lower the Partnership’s senior unsecured debt rating to a below investment grade rating, at March 31, 2015, the Partnership would have been required to post no cash collateral to satisfy its obligation under its financial and physical contracts relating to derivative instruments that are in a net liability position at March 31, 2015. In addition, the Partnership could be required to provide additional credit assurances in future dealings with third parties, which could include letters of credit or cash 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
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-Name Accounting Standards Codification
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+ Details

Supplemental Disclosure of Cash Flow Information

3 Months Ended

Mar. 31, 2015

Supplemental Cash Flow Information [Abstract]

Supplemental Disclosure of Cash Flow Information

The following table provides information regarding supplemental cash flow information:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	9	$	15
Non-cash transactions:
Accounts payable related to capital expenditures	51		17

Related Party Transactions

3 Months Ended

Mar. 31, 2015

Related Party Transactions

The material related party transactions with CenterPoint Energy, OGE Energy and their respective subsidiaries are summarized below. There were no material related party transactions with other affiliates.

The Partnership’s revenues from affiliated companies accounted for 8% and 6% of revenues during the three months ended March 31, 2015 and 2014, respectively. Amounts of revenues from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income are summarized as follows:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Gas transportation and storage - CenterPoint Energy	$	33	$	33
Gas sales - CenterPoint Energy	6		15
Gas transportation and storage - OGE Energy ⁽¹⁾	9		12
Gas sales - OGE Energy⁽¹⁾	3		5
Total revenues - affiliated companies	$	51	$	65

____________________

(1)

The Partnership's contracts with OGE Energy to transport and sell natural gas to OGE Energy’s natural gas-fired generation facilities and store natural gas are reflected in Partnership’s Condensed Consolidated Statement of Income beginning on May 1, 2013. On March 17, 2014, the Partnership and the electric utility subsidiary of OGE Energy signed a new transportation agreement effective May 1, 2014 with a primary term through April 30, 2019. Following the primary term, the agreement will remain in effect from year to year thereafter unless either party provides notice of termination to the other party at least 180 days prior to the commencement of the succeeding annual period.

Amounts of natural gas purchased from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income are summarized as follows:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Cost of goods sold - CenterPoint Energy	$	1	$	1
Cost of goods sold - OGE Energy	3		3
Total cost of goods sold - affiliated companies	$	4	$	4

Prior to May 1, 2013, the Partnership had employees and reflected the associated benefit costs directly and not as corporate services. Under the terms of the MFA, effective May 1, 2013 the Partnership’s employees were seconded by CenterPoint Energy and OGE Energy, and the Partnership began reimbursing each of CenterPoint Energy and OGE Energy for all employee costs under the seconding agreements until the seconded employees transition from CenterPoint Energy and OGE Energy to the Partnership. The Partnership transitioned seconded employees from CenterPoint Energy and OGE Energy to the Partnership effective January 1, 2015, except for certain employees who are participants under OGE Energy’s defined benefit and retiree medical plans, who will remain seconded to the Partnership, subject to certain termination rights of the Partnership and OGE Energy. The Partnership’s reimbursement of OGE Energy for employee costs arising out of OGE Energy’s defined benefit and retiree medical plans is fixed at $6 million in each of 2015 and 2016, $5 million in 2017, and at actual cost subject to a cap of $5 million in 2018 and thereafter, in the event of continued secondment.

Prior to May 1, 2013, the Partnership received certain services and support functions from CenterPoint Energy described below. Under the terms of the MFA, effective May 1, 2013, the Partnership receives services and support functions from each of CenterPoint Energy and OGE Energy under service agreements for an initial term ending on April 30, 2016. The service agreements automatically extend year-to-year at the end of the initial term, unless terminated by the Partnership with at least 90 days’ notice. Additionally, the Partnership may terminate these service agreements at any time with 180 days’ notice, if approved by the Board of Enable GP. The Partnership reimburses CenterPoint Energy and OGE Energy for these services up to annual caps, which for 2015 are $10 million and $11 million, respectively.

Effective April 1, 2014, the Partnership, CenterPoint Energy and OGE Energy agreed to reduce certain allocated costs charged to the Partnership because the Partnership has assumed responsibility for the related activities.

Amounts charged to the Partnership by affiliates for seconded employees and corporate services, included primarily in operating and maintenance expenses in Partnership’s Condensed Consolidated Statements of Income are as follows:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Seconded Employee Costs - CenterPoint Energy	$	—	$	38
Corporate Services - CenterPoint Energy	4		11
Seconded Employee Costs - OGE Energy	9		31
Corporate Services - OGE Energy	3		6
Total corporate services and seconded employees expense	$	16	$	86

The Partnership has outstanding long-term notes payable—affiliated companies to CenterPoint Energy at both March 31, 2015 and December 31, 2014 of $363 million which mature in 2017. Notes having an aggregate principal amount of approximately $273 million bear a fixed interest rate of 2.10% and notes having an aggregate principal amount of approximately $90 million bear a fixed interest rate of 2.45%.

The Partnership recorded affiliated interest expense to CenterPoint Energy on note payable—affiliated companies of $2 million during each of the three months ended March 31, 2015 and 2014, respectively.

- 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

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies The Partnership is involved in legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. Some of these proceedings involve substantial amounts. The Partnership regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. The Partnership does not expect the disposition of these matters to have a material adverse effect on its financial condition, results of operations or cash flows.

Equity Based Compensation

3 Months Ended

Mar. 31, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Equity Based Compensation

The following table summarizes the Partnership’s compensation expense for the three months ended March 31, 2015 and 2014 related to performance units, restricted units, and phantom units for the Partnership's employees.



	Three Months Ended March 31,
	2015		2014
	(In millions)
Performance units	$	1	$	—
Restricted units	2		—
Phantom units	—		—
Total compensation expense	$	3	$	—

Units Outstanding

A summary of the activity for the Partnership's performance units, restricted units, and phantom units applicable to the Partnership’s employees at March 31, 2015 and changes during 2015 are shown in the following table.



	Performance Units				Restricted Units				Phantom Units
	Number of Units		Aggregate Intrinsic Value		Number of Units		Aggregate Intrinsic Value		Number of Units		Aggregate Intrinsic Value
	(In millions, except unit data)
Units Outstanding at December 31, 2014	552,581				838,068				98,718
Granted⁽¹⁾	—				45,230				—
Vested	(712	)			(137,961	)			—
Forfeited	(42,130	)			(12,641	)			(2,000	)
Units Outstanding at March 31, 2015	509,739		$	7	732,696		$	14	96,718		$	2
Units Fully Vested at March 31, 2015	2,257								500

_____________________


(1)	For performance units, this represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

Unrecognized Compensation Cost

A summary of the Partnership's unrecognized compensation cost for its non-vested performance units, restricted units, and phantom units, and the weighted-average periods over which the compensation cost is expected to be recognized are shown in the following table.



	March 31, 2015
	Unrecognized Compensation Cost (In millions)		Weighted Average to be Recognized (In years)
Performance Units	$	9	2.17
Restricted Units	12		2.06
Phantom Units	—		0.11
Total	$	21

As of March 31, 2015, there were 11,470,160 units available for issuance under the long term incentive plan.

Reportable Business Segments

3 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

Reportable Business Segments

Reportable Segments

The Partnership’s determination of reportable segments considers the strategic operating units under which it manages sales, allocates resources and assesses performance of various products and services to wholesale or retail customers in differing regulatory environments. The accounting policies of the reportable segments are the same as those described in the summary of significant accounting policies excerpt in the Partnership’s audited 2014 combined and consolidated financial statements included in the Annual Report. The Partnership uses operating income as the measure of profit or loss for its reportable segments.

The Partnership’s assets and operations are organized into two reportable segments: (i) Gathering and Processing, which primarily provides natural gas gathering, processing and fractionation services and crude oil gathering for our producer customers, and (ii) Transportation and Storage, which provides interstate and intrastate natural gas pipeline transportation and storage service primarily to natural gas producers, utilities and industrial customers.

Financial data for reportable segments and services are as follows:



Three Months Ended March 31, 2015	Gathering and Processing		Transportation and Storage⁽¹⁾		Eliminations			Total
	(In millions)
Revenues	$	401	$	308	$	(93	)	$	616
Cost of goods sold, excluding depreciation and amortization	222		163		(93		)	292
Operation and maintenance	76		54		—			130
Depreciation and amortization	43		30		—			73
Taxes other than income tax	8		9		—			17
Operating income	$	52	$	52	$	—		$	104
Total assets	$	10,231	$	8,127	$	(6,390	)	$	11,968
Capital expenditures	$	215	$	24	$	—		$	239


Three Months Ended March 31, 2014	Gathering and Processing		Transportation and Storage⁽¹⁾		Eliminations			Total
	(In millions)
Revenues	$	671	$	528	$	(197	)	$	1,002
Cost of goods sold, excluding depreciation and amortization	464		366		(197		)	633
Operation and maintenance	69		57		—			126
Depreciation and amortization	38		29		—			67
Taxes other than income tax	4		10		—			14
Operating income	$	96	$	66	$	—		$	162
Total assets as of December 31, 2014	$	8,356	$	5,493	$	(2,012	)	$	11,837
Capital expenditures	$	129	$	21	$	(1	)	$	149

_____________________

(1)

Transportation and Storage recorded equity income of $7 million and $3 million for the three months ended March 31, 2015 and 2014, respectively, from its interest in SESH, a jointly-owned pipeline. These amounts are included in Equity in earnings of equity method affiliates under the Other Income (Expense) caption. Transportation and Storage’s investment in SESH was $349 million and $348 million as of March 31, 2015 and December 31, 2014, respectively, and is included in Investments in equity method affiliates. The Partnership reflected a 24.95% interest in SESH for the period of December 31, 2013 until May 29, 2014. On May 30, 2014, CenterPoint Energy contributed its 24.95% interest in SESH to the Partnership. As of March 31, 2015, the Partnership owns 49.90% interest in SESH. See Note 6 for further discussion regarding SESH.

- 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
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-Name Accounting Standards Codification
-Topic 280
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Paragraph 32
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-Section 50
-Paragraph 26
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-Paragraph 35
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-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
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-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
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Reference 12: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-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

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On May 1, 2015, the Partnership completed an $80 million acquisition of certain natural gas gathering assets in the Texas Panhandle from Monarch Natural Gas, LLC.

Summary of Significant Accounting Policies (Policies)	3 Months Ended
Summary of Significant Accounting Policies (Policies)	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization Enable Midstream Partners, LP (Partnership) is a Delaware limited partnership formed on May 1, 2013 by CenterPoint Energy, Inc. (CenterPoint Energy), OGE Energy Corp. (OGE Energy) and affiliates of ArcLight Capital Partners, LLC (ArcLight), pursuant to the terms of the MFA. The Partnership is a large-scale, growth-oriented limited partnership formed to own, operate and develop strategically located natural gas and crude oil infrastructure assets. The Partnership’s assets and operations are organized into two reportable segments: (i) Gathering and Processing, which primarily provides natural gas gathering, processing and fractionation services and crude oil gathering for our producer customers, and (ii) Transportation and Storage, which provides interstate and intrastate natural gas pipeline transportation and storage service primarily to natural gas producers, utilities and industrial customers. The natural gas gathering and processing assets are located in five states and serve natural gas production in the Anadarko, Arkoma and Tex-La basins. This segment also includes a crude oil gathering business in the Bakken Shale formation, principally located in the Williston basin. The natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois. The Partnership is controlled equally by CenterPoint Energy and OGE Energy, who each have 50% of the management rights of Enable GP. Enable GP was established by CenterPoint Energy and OGE Energy to govern the Partnership and has no other operating activities. Enable GP is governed by a board made up of an equal number of representatives designated by each of CenterPoint Energy and OGE Energy, along with the Partnership's Chief Executive Officer and the independent board members CenterPoint Energy and OGE Energy mutually agreed to appoint. Based on the 50/50 management ownership, with neither company having control, CenterPoint Energy and OGE Energy do not consolidate their interests in the Partnership. CenterPoint Energy and OGE Energy also own a 40% and 60% interest, respectively, in the incentive distribution rights held by Enable GP. At March 31, 2015, CenterPoint Energy held approximately 55.4% of the limited partner interests in the Partnership, or 94,126,366 common units and 139,704,916 subordinated units, and OGE Energy held approximately 26.3% of the limited partner interests in the Partnership, or 42,832,291 common units and 68,150,514 subordinated units. For the period from December 31, 2013 through May 29, 2014, the financial statements reflect a 24.95% interest in SESH. For the period of May 30, 2014 through March 31, 2015, the financial statements reflect a 49.90% interest in SESH. See Note 6 for further discussion of SESH. On April 16, 2014, the Partnership completed the Offering of 25,000,000 common units, representing limited partner interests in the Partnership, at a price to the public of $20.00 per common unit. The Partnership received net proceeds of $464 million from the sale of the common units, after deducting underwriting discounts and commissions, the structuring fee and offering expenses. In connection with the Offering, underwriters exercised their option to purchase 3,750,000 additional common units, which were fulfilled with units held by ArcLight. As a result, the Partnership did not receive any proceeds from the sale of common units pursuant to the exercise of the underwriters' option to purchase additional common units. The exercise of the underwriters' option to purchase additional common units did not affect the total number of units outstanding or the amount of cash needed to pay the minimum quarterly distribution on all outstanding units. The Partnership retained the net proceeds of the Offering for general partnership purposes, including the funding of expansion capital expenditures, and to pre-fund demand fees expected to be incurred over the next three years relating to certain expiring transportation and storage contracts. In connection with the Offering, 139,704,916 of CenterPoint Energy's common units and 68,150,514 of OGE Energy's common units were converted into subordinated units.
Basis of Presentation	Basis of Presentation The accompanying condensed consolidated financial statements and related notes of the Partnership have been prepared pursuant to the rules and regulations of the SEC and GAAP. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with GAAP have been omitted. The accompanying condensed consolidated financial statements and related notes should be read in conjunction with the combined and consolidated financial statements and related notes included in our Annual Report. These condensed consolidated financial statements and the related financial statement disclosures reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position and results of operations for the respective periods. Amounts reported in the Partnership’s Condensed Consolidated Statements of 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.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP 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.
Income Tax, Policy [Policy Text Block]	Income Taxes As a limited partnership, the Partnership’s earnings are no longer subject to income tax (other than Texas state margin taxes and taxes associated with the Partnership's corporate subsidiary) and are taxable at the individual partner level, with the exception of Enable Midstream Services, LLC, a wholly owned subsidiary (Enable Midstream Services). The Partnership and its subsidiaries are pass-through entities for federal income tax purposes. For these entities, all income, expenses, gains, losses and tax credits generated flow through to their owners and, accordingly, do not result in a provision for income taxes in the consolidated financial statements.

- Definition

Disclosure of accounting policy for income taxes, which may include its accounting policies for recognizing and measuring deferred tax assets and liabilities and related valuation allowances, recognizing investment tax credits, operating loss carryforwards, tax credit carryforwards, and other carryforwards, methodologies for determining its effective income tax rate and the characterization of interest and penalties in the financial statements.

+ References + Details

Earnings Per Limited Partner Unit (Tables)

3 Months Ended

Mar. 31, 2015

Earnings Per Share [Abstract]

Schedule Of Earnings Per Unit For Common And Subordinated Limited Partner Units [Table Text Block]

The following table illustrates the Partnership’s calculation of earnings per unit for common and subordinated limited partner units:



	Three Months Ended March 31,
	2015		2014
	(In millions, except per unit data)
Net income attributable to Enable Midstream Partners, LP	$	91	$	149
Less general partner interest in net income	—		—
Limited partner interest in net income attributable to Enable Midstream Partners, LP	$	91	$	149
Net income allocable to common units	$	48	$	149
Net income allocable to subordinated units	43		—
Limited partner interest in net income attributable to Enable Midstream Partners, LP	$	91	$	149
Basic and diluted weighted average number of outstanding limited partner units
Common units	214		390
Subordinated units⁽¹⁾	208		—
Total	422		390
Basic and diluted earnings per limited partner unit
Common units	$	0.22	$	0.38
Subordinated units⁽¹⁾	$	0.21	$	—

Enable Midstream Partners, LP Partners' Capital (Tables)

3 Months Ended

Mar. 31, 2015

Equity [Abstract]

Schedule Of Equity Transactions With Limited Partner



Quarter Ended	Record Date	Payment Date	Per Unit Distribution		Total Cash Distribution
March 31, 2015⁽¹⁾	May 5, 2015	May 15, 2015	$	0.3125	$	132
December 31, 2014	February 4, 2015	February 13, 2015	$	0.30875	$	130
September 30, 2014	November 4, 2014	November 14, 2014	$	0.3025	$	128
June 30, 2014 ⁽²⁾	August 4, 2014	August 14, 2014	$	0.2464	$	104

_____________________


(1)	The board of directors of Enable GP declared this $0.3125 per common unit cash distribution on April 24, 2015, to be paid on May 15, 2015, to unitholders of record at the close of business on May 5, 2015.


(2)	The quarterly distribution for three months ended June 30, 2014 was prorated for the period beginning immediately after the closing of the Partnership's Offering, April 16, 2014 through June 30, 2014.

Intangible Assets, Net (Tables)

3 Months Ended

Mar. 31, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Finite-Lived Intangible Assets [Table Text Block]

Intangible assets consist of the following:



	March 31, 2015		December 31, 2014
	(In millions)
Customer relationships:
Total intangible assets	$	401	$	401
Accumulated amortization	51		45
Net intangible assets	$	350	$	356

Investment in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Investments Detail

Investment in Equity Method Affiliates:



	Three Months Ended March 31,
	2015			2014
	(In millions)
Balance as of December 31	$	348		$	198
Equity in earnings of equity method affiliate	7			3
Contributions to equity method affiliate	6			—
Distributions from equity method affiliate	(12		)	(3		)
Balance as of March 31	$	349		$	198

Equity in Earnings of Equity Method Affiliates:



	Three Months Ended March 31,
	2015		2014
	(In millions)
SESH	$	7	$	3

Distributions from Equity Method Affiliates:



	Three Months Ended March 31,
	2015		2014
	(In millions)
SESH	$	12	$	3

Summarized financial information of SESH is presented below:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Income Statements:
Revenues	$	29	$	27
Operating income	18		17
Net income	14		12

Debt (Tables)

3 Months Ended

Mar. 31, 2015

Debt Disclosure [Abstract]

Schedule of Debt [Table Text Block]

The following table presents the Partnership's outstanding debt as of March 31, 2015 and December 31, 2014.



	March 31, 2015		December 31, 2014
	(In millions)
Commercial Paper	$	436	$	253
Notes payable — affiliated companies	363		363
2019 Notes	500		500
2024 Notes	600		600
2044 Notes	550		550
Enable Oklahoma Senior Notes	250		250
Premium (Discount) on long-term debt	26		28
Total debt	2,725		2,544
Less amount classified as short-term debt⁽¹⁾	436		253
Less Notes payable—affiliated companies	363		363
Total long-term debt	$	1,926	$	1,928

___________________


(1)	Short-term debt includes $436 million and $253 million of commercial paper as of March 31, 2015 and December 31, 2014, respectively.

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2015

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following tables summarize the Partnership’s assets and liabilities that are measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014:



March 31, 2015	Commodity Contracts						Gas Imbalances ⁽¹⁾
	Assets			Liabilities			Assets ⁽²⁾		Liabilities ⁽³⁾
	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	26		$	4		$	—	$	—
Significant other observable inputs (Level 2)	1			—			29		$	5
Unobservable inputs (Level 3)	7			—			—		$	—
Total fair value	34			4			29		$	5
Netting adjustments	(4		)	(4		)	—		$	—
Total	$	30		$	—		$	29	$	5



December 31, 2014	Commodity Contracts						Gas Imbalances ⁽¹⁾
	Assets			Liabilities			Assets ⁽²⁾		Liabilities ⁽³⁾
	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	33		$	4		$	—	$	—
Significant other observable inputs (Level 2)	2			—			40		12
Unobservable inputs (Level 3)	5			—			—		—
Total fair value	40			4			40		12
Netting adjustments	(4		)	(4		)	—		—
Total	$	36		$	—		$	40	$	12

______________________

(1)


(2)	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $8 million and $4 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.


(3)	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $1 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.

Schedule of Fair Value and Carrying Amount of Financial Instruments

The following table summarizes the fair value and carrying amount of the Partnership’s financial instruments at March 31, 2015 and December 31, 2014.



	March 31, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)
Long-Term Debt
Long-term notes payable - affiliated companies (Level 2)	$	363	$	365	$	363	$	362
Revolving Credit Facility (Level 2)⁽¹⁾	—		—		—		—
Enable Oklahoma Senior Notes (Level 2)⁽²⁾	277		282		279		282
Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2)	1,649		1,568		1,649		1,592

___________________


(1)	Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $436 million and $253 million of commercial paper was outstanding as of March 31, 2015 and December 31, 2014, respectively.


(2)	No amount was included in short term debt as of March 31, 2015 and December 31, 2014, respectively.

Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments

As of March 31, 2015 and December 31, 2014, the Partnership had the following derivative instruments that were not designated as hedging instruments for accounting purposes:



	March 31, 2015		December 31, 2014
	Gross Notional Volume
	Purchases	Sales	Purchases	Sales
Natural gas—TBtu⁽¹⁾
Physical purchases/sales	5	67	4	32
Financial fixed futures/swaps	5	34	5	35
Financial basis futures/swaps	4	40	7	54
Condensate—MBbl⁽²⁾
Financial Futures/swaps	—	970	—	12
Natural gas liquids—MBbl⁽³⁾
Financial Futures/swaps	—	714	—	—

____________________

(1)


(2)	As of March 31, 2015, 75.5% of the condensate contracts had durations of one year or less and 24.5% had durations of more than one year and less than two years. As of December 31, 2014, 100.0% of the condensate contracts had durations of one year or less.


(3)	As of March 31, 2015, 100.0% of the natural gas liquids contracts had durations of one year or less.

Schedule of Derivative Assets at Fair Value



		March 31, 2015				December 31, 2014
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
		(In millions)
Natural gas
Financial futures/swaps	Other Current	$	27	$	4	$	34	$	4
Physical purchases/sales	Other Current	1		—		1		—
Condensate
Financial futures/swaps	Other Current	6		—		5		—
Natural gas liquids
Financial Futures/swaps	Other Current	—		—		—		—
Total gross derivatives ⁽¹⁾		$	34	$	4	$	40	$	4

_____________________


(1)	See Note 8 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of March 31, 2015 and December 31, 2014.

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following tables present the effect of derivative instruments on the Partnership’s Condensed Consolidated Statement of Income for the three months ended March 31, 2015.



	Amounts Recognized in Income
	Three Months Ended March 31,
	2015			2014
	(In millions)
Natural gas financial futures/swaps gains (losses)	$	7		$	2
Natural gas physical purchases/sales gains (losses)	(4		)	2
Condensate financial futures/swaps gains (losses)	4			—
Natural gas liquids financial futures/swaps gains (losses)	—			—
Total	$	7		$	4

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: 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 2: 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 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41678-113959

Reference 4: 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 5: 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 6: 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 7: 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 8: 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 9: 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 10: 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 11: 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)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Supplemental Disclosure of Cash Flow Information Supplemental Disclosure of Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2015

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

The following table provides information regarding supplemental cash flow information:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	9	$	15
Non-cash transactions:
Accounts payable related to capital expenditures	51		17

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2015

Schedule of Revenues from Related Parties

Amounts of revenues from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income are summarized as follows:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Gas transportation and storage - CenterPoint Energy	$	33	$	33
Gas sales - CenterPoint Energy	6		15
Gas transportation and storage - OGE Energy ⁽¹⁾	9		12
Gas sales - OGE Energy⁽¹⁾	3		5
Total revenues - affiliated companies	$	51	$	65

____________________

(1)

Schedule of Natural Gas Purchased From Related Parties

Amounts of natural gas purchased from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income are summarized as follows:



	Three Months Ended March 31,
	2015		2014
	(In millions)
Cost of goods sold - CenterPoint Energy	$	1	$	1
Cost of goods sold - OGE Energy	3		3
Total cost of goods sold - affiliated companies	$	4	$	4

Schedule of Amounts Charged to Partnership by Related Parties



	Three Months Ended March 31,
	2015		2014
	(In millions)
Seconded Employee Costs - CenterPoint Energy	$	—	$	38
Corporate Services - CenterPoint Energy	4		11
Seconded Employee Costs - OGE Energy	9		31
Corporate Services - OGE Energy	3		6
Total corporate services and seconded employees expense	$	16	$	86

Equity Based Compensation (Tables)

3 Months Ended

Mar. 31, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award



	Three Months Ended March 31,
	2015		2014
	(In millions)
Performance units	$	1	$	—
Restricted units	2		—
Phantom units	—		—
Total compensation expense	$	3	$	—

Schedule of Share-based Compensation, Activity



	Performance Units				Restricted Units				Phantom Units
	Number of Units		Aggregate Intrinsic Value		Number of Units		Aggregate Intrinsic Value		Number of Units		Aggregate Intrinsic Value
	(In millions, except unit data)
Units Outstanding at December 31, 2014	552,581				838,068				98,718
Granted⁽¹⁾	—				45,230				—
Vested	(712	)			(137,961	)			—
Forfeited	(42,130	)			(12,641	)			(2,000	)
Units Outstanding at March 31, 2015	509,739		$	7	732,696		$	14	96,718		$	2
Units Fully Vested at March 31, 2015	2,257								500

Schedule of Unrecognized Compensation Cost, Nonvested Awards



	March 31, 2015
	Unrecognized Compensation Cost (In millions)		Weighted Average to be Recognized (In years)
Performance Units	$	9	2.17
Restricted Units	12		2.06
Phantom Units	—		0.11
Total	$	21

Report of Business Segments (Tables)

3 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

Schedule of Financial Data for Business Segments and Services

Financial data for reportable segments and services are as follows:



Three Months Ended March 31, 2015	Gathering and Processing		Transportation and Storage⁽¹⁾		Eliminations			Total
	(In millions)
Revenues	$	401	$	308	$	(93	)	$	616
Cost of goods sold, excluding depreciation and amortization	222		163		(93		)	292
Operation and maintenance	76		54		—			130
Depreciation and amortization	43		30		—			73
Taxes other than income tax	8		9		—			17
Operating income	$	52	$	52	$	—		$	104
Total assets	$	10,231	$	8,127	$	(6,390	)	$	11,968
Capital expenditures	$	215	$	24	$	—		$	239


Three Months Ended March 31, 2014	Gathering and Processing		Transportation and Storage⁽¹⁾		Eliminations			Total
	(In millions)
Revenues	$	671	$	528	$	(197	)	$	1,002
Cost of goods sold, excluding depreciation and amortization	464		366		(197		)	633
Operation and maintenance	69		57		—			126
Depreciation and amortization	38		29		—			67
Taxes other than income tax	4		10		—			14
Operating income	$	96	$	66	$	—		$	162
Total assets as of December 31, 2014	$	8,356	$	5,493	$	(2,012	)	$	11,837
Capital expenditures	$	129	$	21	$	(1	)	$	149

_____________________

(1)

Summary of Significant Accounting Policies - Narrative (Details) $ / shares in Units, $ in Millions			3 Months Ended		13 Months Ended
	Apr. 16, 2014 USD ($) $ / shares shares	Mar. 25, 2014	Mar. 31, 2015 USD ($) shares	Mar. 31, 2014 USD ($)	May 29, 2014	Apr. 30, 2013
Income tax benefit \| $			$ 1	$ 1
Conversion ratio		1.279082616
CenterPoint
Limited partner ownership interest			55.40%
Percentage share of management rights			50.00%
Percentage share of incentive distribution rights			40.00%
OGE Energy
Limited partner ownership interest			26.30%
Percentage share of management rights			50.00%
Percentage share of incentive distribution rights			60.00%
SESH
Ownership percentage			49.90%			50.00%
Limited partner ownership interest, exercisable as early as May 2014					24.95%
SESH \| CenterPoint
Distributed ownership percentage					25.05%
Common Units \| CenterPoint
Units outstanding			94,126,366
Common Units \| OGE Energy
Units outstanding			42,832,291
Subordinated Units \| CenterPoint
Units outstanding			139,704,916
Subordinated Units \| OGE Energy
Units outstanding			68,150,514
IPO \| Common Units
Common units issued during period (in shares)	25,000,000
Initial public offering price (in dollars per share) \| $ / shares	$ 20.00
Net proceeds from sale of common units, net of underwriting discounts, commissions, and other related expenses \| $	$ 464
IPO \| Common Units \| CenterPoint
Conversion of stock, common units converted (in shares)	139,704,916
IPO \| Common Units \| OGE Energy
Conversion of stock, common units converted (in shares)	68,150,514
Over-Allotment Option \| Common Units
Common units issued during period (in shares)	3,750,000

Earnings Per Limited Partner Unit (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

3 Months Ended

Mar. 31, 2015

Mar. 31, 2014

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

Net income attributable to Enable Midstream Partners, LP

$ 91

$ 149

Less general partner interest in net income

Net income attributable to Enable Midstream Partners, LP

$ 91

$ 149

Basic and diluted weighted average number of outstanding limited partner units

Basic and diluted weighted average number of outstanding limited partner units (in units)

422

390

Basic and diluted earnings per limited partner unit

Dilutive effect of unit-based awards

$ 0

Common Units

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

Net income attributable to Enable Midstream Partners, LP

$ 48

$ 149

Basic and diluted weighted average number of outstanding limited partner units

Basic and diluted weighted average number of outstanding limited partner units (in units)

214

390

Basic and diluted earnings per limited partner unit

Basic and diluted earnings per unit (in dollars per unit)

$ 0.22

$ 0.38

Subordinated Units

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

Net income attributable to Enable Midstream Partners, LP

$ 43

$ 0

Basic and diluted weighted average number of outstanding limited partner units

Basic and diluted weighted average number of outstanding limited partner units (in units)

^[1]

208

Basic and diluted earnings per limited partner unit

Basic and diluted earnings per unit (in dollars per unit)

^[1]

$ 0.21

$ 0.00

[1]	Basic and diluted earnings per subordinated unit reflect net income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

Enable Midstream Partners, LP Partners' Capital (Details) - USD ($) $ in Millions				13 Months Ended
	Aug. 14, 2014	May 14, 2014	Feb. 14, 2014	May 29, 2014
Distribution Made to Limited Partner [Line Items]
Net distributions to CenterPoint Energy prior to formation	$ (22)	$ (155)	$ (114)
CenterPoint \| SESH
Distribution Made to Limited Partner [Line Items]
Distributed ownership percentage				25.05%

Enable Midstream Partners, LP Partners' Capital Cash Distribution post IPO (Details) - USD ($)
$ / shares in Units, $ in Millions

May 15, 2015

May 05, 2015

Feb. 13, 2015

Feb. 04, 2015

Nov. 14, 2014

Nov. 04, 2014

Aug. 14, 2014

Aug. 05, 2014

^[1]

Distribution Made to Limited Partner [Line Items]

Record Date

Feb. 04, 2015

Nov. 04, 2014

Aug. 04, 2014

Payment Date

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

^[1]

Cash Distribution

Distribution Made to Limited Partner [Line Items]

Per unit distribution, paid (per common unit)

^[2]

$ 0.2464

Distribution made to unitholders

^[2]

$ 104

Quarterly cash distribution declared (per common unit)

$ 0.30875

$ 0.3025

Cash distributions declared

$ 130

$ 128

Subsequent Event

Distribution Made to Limited Partner [Line Items]

Record Date

^[2]

May 05, 2015

Payment Date

^[1]

May 15, 2015

Subsequent Event | Cash Distribution

Distribution Made to Limited Partner [Line Items]

Quarterly cash distribution declared (per common unit)

^[2]

$ 0.3125

Cash distributions declared

^[2]

$ 132

[1]	The quarterly distribution for three months ended June 30, 2014 was prorated for the period beginning immediately after the closing of the Partnership's Offering, April 16, 2014 through June 30, 2014.
[2]	The board of directors of Enable GP declared this $0.3125 per common unit cash distribution on April 24, 2015, to be paid on May 15, 2015, to unitholders of record at the close of business on May 5, 2015.

Enable Midstream Partners, LP Partners' Capital Textual (Details) - USD ($) $ / shares in Units, $ in Millions				3 Months Ended
	Aug. 14, 2014	May 14, 2014	Feb. 14, 2014	Mar. 31, 2015
Distribution Made to Limited Partner [Line Items]
Limited partners' capital account, distribution amount	$ 22	$ 155	$ 114
Limited partners' capital account, required quarterly distribution period				45 days
Incentive distribution, distribution per unit				$ 0.330625
Limited partners capital account, minimum quarterly distribution, annualized				150.00%
Subordinated Units
Distribution Made to Limited Partner [Line Items]
Minimum quarterly distribution per common unit				$ 0.2875
Distribution Subordination Period 1
Distribution Made to Limited Partner [Line Items]
Limited partners' capital account, minimum annualized quarterly distribution per unit				1.15
Distribution Subordination Period 2
Distribution Made to Limited Partner [Line Items]
Limited partners' capital account, maximum annualized quarterly distribution per unit				$ 1.725
Maximum
Distribution Made to Limited Partner [Line Items]
Limited partners' capital account, incentive distribution rights, percentage				50.00%

Intangible Assets, Net - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 6	$ 7
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 401		$ 401
Weighted average useful life	15 years
Finite-Lived Intangible Assets, Accumulated Amortization	$ 51		45
Finite-Lived Intangible Assets, Net	$ 350		$ 356

Investment in Equity Method Affiliates - Narrative (Details) - USD ($) $ in Millions			3 Months Ended		13 Months Ended
	Jul. 25, 2014	May 01, 2013	Mar. 31, 2015	Mar. 31, 2014	May 29, 2014	Dec. 31, 2014	Sep. 30, 2014	Dec. 31, 2013	Apr. 30, 2013
Equity Method Investments			$ 349			$ 348
SESH
Limited partner units that may be issued, exercisable as early as May 2014		6,322,457
Limited partner units that may be issued, exercisable as early as May 2015		25,341
Limited partner ownership interest, exercisable as early as May 2015		0.10%
CenterPoint
Distribution to limited partner in third quarter, ended September 30, 2014							$ 1
SESH
Ownership percentage			49.90%						50.00%
Limited partner ownership interest, exercisable as early as May 2014					24.95%
Equity Method Investment, Distributed			$ 12	$ 3
SESH \| CenterPoint
Distributed ownership percentage					25.05%
Investments in Equity Method Affiliates \| SESH
Equity Method Investment, Distributed	$ 7		12	3
Equity Method Investments			$ 349	$ 198		$ 348		$ 198

Investment in Equity Method Affiliates - Schedule of Investments (Details) - USD ($) $ in Millions		3 Months Ended
	Jul. 25, 2014	Mar. 31, 2015	Mar. 31, 2014
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balance as of December 31		$ 348
Equity in earnings of equity method affiliates		7	$ 3
Balance as of March 31		349
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates		7	3
SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Distributions from unconsolidated affiliates		(12)	(3)
Distributions from Equity Method Affiliates:
Distributions from unconsolidated affiliates		(12)	(3)
Operating revenues		29	27
Operating income		18	17
Net income		14	12
Other Income (Expense) \| SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity in earnings of equity method affiliates		7	3
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates		7	3
Investments in Equity Method Affiliates \| SESH
Schedule of Equity Method Investments [Line Items]
Capital contributions from partners		6	0
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balance as of December 31		348	198
Equity in earnings of equity method affiliates		7	3
Distributions from unconsolidated affiliates	$ (7)	(12)	(3)
Balance as of March 31		349	198
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates		7	3
Distributions from Equity Method Affiliates:
Distributions from unconsolidated affiliates	$ (7)	$ (12)	$ (3)

- Narrative (Details) - USD ($)	Mar. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Commercial paper, authorized	$ 1,400,000,000
Carrying value	436,000,000	$ 253,000,000
Long-Term Debt	2,725,000,000	2,544,000,000
Notes payable — affiliated companies	363,000,000	363,000,000
Unamortized premium		28,000,000
Short-term debt	436,000,000	253,000,000
Long-Term Debt	1,926,000,000	1,928,000,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Long-Term Debt	436,000,000	253,000,000
Senior Notes
Debt Instrument [Line Items]
Unamortized premium	26,000,000
Senior Notes \| 2.400% Senior Notes
Debt Instrument [Line Items]
Long-Term Debt	500,000,000	500,000,000
Senior Notes \| 3.900% Senior Notes
Debt Instrument [Line Items]
Long-Term Debt	600,000,000	600,000,000
Senior Notes \| 5.000% Senior Notes
Debt Instrument [Line Items]
Long-Term Debt	550,000,000	550,000,000
Senior Notes \| 6.25% Senior Notes
Debt Instrument [Line Items]
Long-Term Debt	250,000,000	250,000,000
Unamortized premium	26,000,000	28,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	1,400,000,000
Letters of credit principal advances	0
Letters of credit outstanding amount	2,000,000
Other Assets
Debt Instrument [Line Items]
Unamortized debt expense	$ 16,000,000	$ 17,000,000

Fair Value Measurements - Fair Value Hierarchy (Details) - USD ($)
$ in Millions

Mar. 31, 2015

Dec. 31, 2014

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

Fuel Reserves for Under Retained Fuel Due From Shippers

$ 8

$ 4

Fuel Reserves For Over Retained Fuel Due To Shippers

Commodity Contracts | Recurring Measurement

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

Derivative Asset

Assets

(4)

Liabilities

(4)

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

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

Derivative Liability

Commodity Contracts | Recurring Measurement | Quoted market prices in active market for identical assets (Level 1)

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

Derivative Asset, Fair Value, Gross Asset

Derivative Liability, Fair Value, Gross Liability

Commodity Contracts | Recurring Measurement | Significant other observable inputs (Level 2)

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

Derivative Asset, Fair Value, Gross Asset

Derivative Liability, Fair Value, Gross Liability

Commodity Contracts | Recurring Measurement | Unobservable inputs (Level 3)

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

Derivative Asset, Fair Value, Gross Asset

Derivative Liability, Fair Value, Gross Liability

Gas Imbalances | Recurring Measurement

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

Derivative Asset

^[1],[2]

Assets

^[1],[2]

Liabilities

^[2],[3]

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

^[1],[2]

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

^[2],[3]

Derivative Liability

^[2],[3]

Gas Imbalances | Recurring Measurement | Quoted market prices in active market for identical assets (Level 1)

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

Derivative Asset, Fair Value, Gross Asset

^[1],[2]

Derivative Liability, Fair Value, Gross Liability

^[2],[3]

Gas Imbalances | Recurring Measurement | Significant other observable inputs (Level 2)

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

Derivative Asset, Fair Value, Gross Asset

^[1],[2]

Derivative Liability, Fair Value, Gross Liability

^[2],[3]

Gas Imbalances | Recurring Measurement | Unobservable inputs (Level 3)

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

Derivative Asset, Fair Value, Gross Asset

^[1],[2]

Derivative Liability, Fair Value, Gross Liability

^[2],[3]

$ 0

[1]	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $8 million and $4 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.
[2]	The Partnership uses the market approach to fair value its gas imbalance assets and liabilities at individual, or where appropriate an average of, current market indices applicable to the Partnership’s operations, not to exceed net realizable value. Gas imbalances held by Enable Oklahoma are valued using an average of the Inside FERC Gas Market Report for Panhandle Eastern Pipe Line Co. (Texas, Oklahoma Mainline), ONEOK (Oklahoma) and ANR Pipeline (Oklahoma) indices. There were no netting adjustments as of March 31, 2015 and December 31, 2014.
[3]	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $1 million at March 31, 2015 and December 31, 2014, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created and which are not subject to revaluation at fair market value.

Fair Value Measurements - Carrying and Fair Value Amounts (Details) - USD ($)

Mar. 31, 2015

Dec. 31, 2014

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Carrying Amount

$ 2,725,000,000

$ 2,544,000,000

Carrying value

436,000,000

253,000,000

Short-term debt

436,000,000

253,000,000

Enable Oklahoma Senior Notes (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Short-term debt

Carrying Amount | Significant other observable inputs (Level 2) | Long-term notes payable - affiliated companies (Level 2) | Affiliated Companies

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Carrying Amount

363,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Revolving Credit Facility (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Carrying Amount

^[1]

Carrying Amount | Significant other observable inputs (Level 2) | Enable Oklahoma Senior Notes (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Carrying Amount

^[2]

277,000,000

279,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Carrying Amount

1,649,000,000

Fair Value | Significant other observable inputs (Level 2) | Long-term notes payable - affiliated companies (Level 2) | Affiliated Companies

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value

365,000,000

362,000,000

Fair Value | Significant other observable inputs (Level 2) | Revolving Credit Facility (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value

^[1]

Fair Value | Significant other observable inputs (Level 2) | Enable Oklahoma Senior Notes (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value

^[2]

282,000,000

Fair Value | Significant other observable inputs (Level 2) | Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2)

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value

$ 1,568,000,000

$ 1,592,000,000

[1]	Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $436 million and $253 million of commercial paper was outstanding as of March 31, 2015 and December 31, 2014, respectively.
[2]	No amount was included in short term debt as of March 31, 2015 and December 31, 2014, respectively.

Derivative Instruments and Hedging Activities (Details) - Not Designated as Hedging Instrument

3 Months Ended

Mar. 31, 2015

MMBTU

MBbls

Mar. 31, 2014

MMBTU

MBbls

Dec. 31, 2014

Natural gas

Derivative [Line Items]

Percent of contract with durations of one year or less

93.50%

91.20%

Percent of contracts with durations of more than one year and less than two years

5.10%

6.50%

Percent of contracts having a duration of more than two years

1.40%

2.20%

Natural gas | Physical | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Natural gas | Physical | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Natural gas | Financial fixed futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Natural gas | Financial fixed futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Natural gas | Financial basis futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Natural gas | Financial basis futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu)

Condensate

Derivative [Line Items]

Percent of contract with durations of one year or less

75.50%

100.00%

Percent of contracts with durations of more than one year and less than two years

24.50%

Condensate | Financial Futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (MMbl) | MBbls

Condensate | Financial Futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (MMbl) | MBbls

970

Natural gas liquids

Derivative [Line Items]

Percent of contract with durations of one year or less

100.00%

Natural gas liquids | Financial Futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (MMbl) | MBbls

^[1]

Natural gas liquids | Financial Futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (MMbl) | MBbls

^[1]

714

[1]	As of March 31, 2015, 100.0% of the natural gas liquids contracts had durations of one year or less.

Derivative Instruments and Hedging Activities - Balance Sheet Location (Details) - Not Designated as Hedging Instrument - USD ($)

Mar. 31, 2015

Dec. 31, 2014

Mar. 31, 2014

Derivatives, Fair Value [Line Items]

Derivative Instruments

$ 0

Assets, Fair Value

34,000,000

^[1]

40,000,000

Liabilities, Fair Value

4,000,000

^[1]

4,000,000

Natural gas | Financial futures/swaps | Other Current

Derivatives, Fair Value [Line Items]

Assets, Fair Value

27,000,000

34,000,000

Natural gas | Financial futures/swaps | Other Current Liabilities [Member]

Derivatives, Fair Value [Line Items]

Liabilities, Fair Value

4,000,000

Natural gas | Physical purchases/sales | Other Current

Derivatives, Fair Value [Line Items]

Assets, Fair Value

1,000,000

Liabilities, Fair Value

Natural gas | Physical purchases/sales | Other Current Liabilities [Member]

Derivatives, Fair Value [Line Items]

Liabilities, Fair Value

Condensate | Financial futures/swaps | Other Current

Derivatives, Fair Value [Line Items]

Assets, Fair Value

6,000,000

5,000,000

Liabilities, Fair Value

Condensate | Financial futures/swaps | Other Current Liabilities [Member]

Derivatives, Fair Value [Line Items]

Liabilities, Fair Value

$ 0

Natural gas liquids | Financial futures/swaps | Other Current

Derivatives, Fair Value [Line Items]

Assets, Fair Value

$ 0

Liabilities, Fair Value

$ 0

[1]	See Note 8 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of March 31, 2015 and December 31, 2014.

Derivative Instruments and Hedging Activities - Amounts Recognized in Income (Details) - USD ($)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	$ 7,000,000	$ 4,000,000
Cash collateral required if ratings are lowered	0
Natural gas \| Physical purchases/sales
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	(4,000,000)	2,000,000
Natural gas \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	7,000,000	2,000,000
Condensate \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	4,000,000	0
Natural gas liquids \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	$ 0	$ 0
Not Designated as Hedging Instrument \| Natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Percent of contract with durations of one year or less	93.50%		91.20%
Percent of contracts with durations of more than one year and less than two years	5.10%		6.50%
Not Designated as Hedging Instrument \| Condensate
Derivative Instruments, Gain (Loss) [Line Items]
Percent of contract with durations of one year or less	75.50%		100.00%
Percent of contracts with durations of more than one year and less than two years	24.50%
Not Designated as Hedging Instrument \| Natural gas liquids
Derivative Instruments, Gain (Loss) [Line Items]
Percent of contract with durations of one year or less	100.00%

Supplemental Disclosure of Cash Flow Information - (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Supplemental Cash Flow Information [Abstract]
Interest, net of capitalized interest	$ 9	$ 15
Accounts payable related to capital expenditures	$ 51	$ 17

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Related Party Transaction [Line Items]
Partnership's revenues from affiliated companies as a percent of total revenues	8.00%	6.00%
Charges to the Partnership by affiliates	$ 16	$ 86
Notes payable—affiliated companies	$ 363		$ 363
OGE Energy
Related Party Transaction [Line Items]
Period notice of termination prior to commencement of succeeding annual period	180 days
OGE Energy \| Defined Benefit and Retiree Medical Plans
Related Party Transaction [Line Items]
Expense reimbursement, remainder of fiscal year	$ 6
Expense reimbursement, second year	6
Expense reimbursement, third year	5
Expense reimbursement, fourth year			5
Expense reimbursement, thereafter	5
OGE Energy \| Certain Services and Support Functions
Related Party Transaction [Line Items]
Expense reimbursement annual caps	11
CenterPoint
Related Party Transaction [Line Items]
Affiliate interest expense	2	$ 2
CenterPoint \| 2.10% Note Payable
Related Party Transaction [Line Items]
Notes payable—affiliated companies	$ 273		$ 273
CenterPoint \| 2.10% Note Payable \| Long-term notes payable - affiliated companies (Level 2)
Related Party Transaction [Line Items]
Fixed interest rate	2.10%		2.10%
CenterPoint \| 2.45% Note Payable
Related Party Transaction [Line Items]
Notes payable—affiliated companies	$ 90		$ 90
CenterPoint \| 2.45% Note Payable \| Long-term notes payable - affiliated companies (Level 2)
Related Party Transaction [Line Items]
Fixed interest rate	2.45%		2.45%
CenterPoint \| Certain Services and Support Functions
Related Party Transaction [Line Items]
Expense reimbursement annual caps	$ 10
CenterPoint and OGE Energy
Related Party Transaction [Line Items]
Period notice of termination for reimbursements for all employee costs	90 days

Related Party Activity (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2015

Mar. 31, 2014

Dec. 31, 2014

Notes payable — affiliated companies

$ 363

Revenues from affiliated companies

$ 65

Cost of goods sold from affiliate

Charges to the Partnership by affiliates

CenterPoint

Notes payable — affiliated companies

363

Cost of goods sold from affiliate

CenterPoint | Gas Transportation and Storage

Revenues from affiliated companies

CenterPoint | Gas Sales

Revenues from affiliated companies

CenterPoint | Seconded Employee Costs

Charges to the Partnership by affiliates

CenterPoint | Corporate Services

Charges to the Partnership by affiliates

OGE Energy

Cost of goods sold from affiliate

OGE Energy | Gas Transportation and Storage

Revenues from affiliated companies

^[1]

OGE Energy | Gas Sales

Revenues from affiliated companies

^[1]

OGE Energy | Seconded Employee Costs

Charges to the Partnership by affiliates

OGE Energy | Corporate Services

Charges to the Partnership by affiliates

$ 3

$ 6

[1]

Equity Based Compensation (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2015

Mar. 31, 2014

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Total compensation expense

$ 3

$ 0

Performance units

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Total compensation expense

$ 1

Units granted

^[1]

Restricted units

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Total compensation expense

$ 2

Units granted

^[1]

45,230

Phantom units

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Total compensation expense

$ 0

Units granted

^[1]

[1]	For performance units, this represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

Equity Based Compensation - Restricted Units (Details) - Restricted units

3 Months Ended

Mar. 31, 2015

$ / shares

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Units granted | shares

45,230

^[1]

Chief Executive Officer | Vesting on February 1, 2016

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting percentage

20.00%

Chief Executive Officer | Vesting on February 1, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting percentage

20.00%

Minimum | Certain Partnership Employees

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Fair value of units granted

$ 24.65

Maximum | Certain Partnership Employees

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Fair value of units granted

$ 25.50

[1]	For performance units, this represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

Equity Based Compensation - Phantom Units (Details)

3 Months Ended

Mar. 31, 2015

Phantom units

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Units granted

^[1]

[1]	For performance units, this represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

Equity Based Compensation - Equity Units Activity (Details)
$ in Millions

3 Months Ended

Mar. 31, 2015

USD ($)

Performance units

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Number of Units Outstanding at 12/31/2013

552,581

Units granted

^[1]

Vested

(712)

Forfeited

(42,130)

Number of Units Outstanding at 06/30/2014

509,739

Aggregate Intrinsic Value, Units Outstanding at 6/30/2014 | $

$ 7

Number of Units Fully Vested at 6/30/2014

2,257

Aggregate Intrinsic Value, Units Fully Vested at 06/30/2014 | $

Restricted units

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Number of Units Outstanding at 12/31/2013

838,068

Units granted

45,230

^[1]

Vested

(137,961)

Forfeited

(12,641)

Number of Units Outstanding at 06/30/2014

732,696

Aggregate Intrinsic Value, Units Outstanding at 6/30/2014 | $

$ 14

Phantom units

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Number of Units Outstanding at 12/31/2013

98,718

Units granted

^[1]

Vested

Forfeited

(2,000)

Number of Units Outstanding at 06/30/2014

96,718

Aggregate Intrinsic Value, Units Outstanding at 6/30/2014 | $

$ 2

Number of Units Fully Vested at 6/30/2014

500

Aggregate Intrinsic Value, Units Fully Vested at 06/30/2014 | $

[1]	For performance units, this represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

Equity Based Compensation - Unrecognized Compensation Cost (Details) $ in Millions	3 Months Ended
	Mar. 31, 2015 USD ($) shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 21
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 9
Weighted Average to be Recognized (In years)	2 years 2 months 1 day
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 12
Weighted Average to be Recognized (In years)	2 years 22 days
Phantom units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 0
Weighted Average to be Recognized (In years)	1 month 10 days
Long Term Incentive Plan \| Common Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance \| shares	11,470,160