Enable Midstream Partners (ENBL) 10-Q 4 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 16, 2015
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Entity Registrant Name	Enable Midstream Partners, LP
Entity Central Index Key	1,591,763
Entity Filer Category	Non-accelerated Filer
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		214,534,491

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues (including revenues from affiliates (Note 12)):
Product sales		$ 357	$ 539	$ 1,043	$ 1,839
Service revenue		289	264	809	793
Total Revenues		646	803	1,852	2,632
Cost and Expenses (including expenses from affiliates (Note 12)):
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)		287	439	856	1,550
Operation and maintenance		130	128	391	383
Depreciation and amortization		84	69	233	205
Impairments (Note 6)		1,105	1	1,105	1
Taxes other than income taxes		15	14	45	41
Total Cost and Expenses		1,621	651	2,630	2,180
Operating (Loss) Income		(975)	152	(778)	452
Other Income (Expense):
Interest expense (including expenses from affiliates (Note 12))		(23)	(20)	(66)	(50)
Equity in earnings of equity method affiliates		7	5	21	12
Other, net		0	3	2	(2)
Total Other Income (Expense)		(16)	(12)	(43)	(40)
(Loss) Income Before Income Taxes		(991)	140	(821)	412
Income tax expense		0	1	2	2
Net (Loss) Income		(991)	139	(823)	410
Less: Net (loss) income attributable to noncontrolling interest		(6)	0	(6)	2
Net (Loss) Income attributable to Enable Midstream Partners, LP		(985)	139	(817)	408
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (985)	$ 139	$ (817)	$ 408
Basic and diluted weighted average number of outstanding limited partner units (in units)		422	422	422	409
Common Units
Other Income (Expense):
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (499)	$ 71	$ (414)	$ 282
Basic and diluted earnings per unit (Note 3) (in dollars per unit)		$ (2.33)	$ 0.33	$ (1.93)	$ 1
Basic and diluted weighted average number of outstanding limited partner units (in units)		214	214	214	281
Subordinated Units
Other Income (Expense):
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (486)	$ 68	$ (403)	$ 126
Basic and diluted earnings per unit (Note 3) (in dollars per unit)	[1]	$ (2.34)	$ 0.33	$ (1.94)	$ 0.98
Basic and diluted weighted average number of outstanding limited partner units (in units)	[1]	208	208	208	128
[1]	Basic and diluted earnings per subordinated unit reflect net (loss) income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

Condensed Consolidated Stateme3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Net (loss) income	$ (991)	$ 139	$ (823)	$ 410
Comprehensive (loss) income	(991)	139	(823)	410
Less: Comprehensive (loss) income attributable to noncontrolling interest	(6)	0	(6)	2
Comprehensive (loss) income attributable to Enable Midstream Partners, LP	$ (985)	$ 139	$ (817)	$ 408

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions		Sep. 30, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents		$ 5	$ 12
Accounts receivable		291	254
Accounts receivable—affiliated companies		25	27
Inventory		52	63
Gas imbalances		16	45
Other current assets		38	37
Total current assets		427	438
Property, Plant and Equipment:
Property, plant and equipment		11,127	10,464
Less accumulated depreciation and amortization		1,089	882
Property, plant and equipment, net		10,038	9,582
Other Assets:
Intangible assets, net		346	357
Goodwill		0	1,068
Investment in equity method affiliates		341	348
Other		49	44
Total other assets		736	1,817
Total Assets		11,201	11,837
Current Liabilities:
Accounts payable		206	275
Accounts payable—affiliated companies		12	38
Short-term debt	[1]	432	253
Taxes accrued		54	23
Gas imbalances		17	13
Other		83	69
Total current liabilities		804	671
Other Liabilities:
Accumulated deferred income taxes, net		10	9
Notes payable—affiliated companies		363	363
Regulatory liabilities		18	16
Other		21	27
Total other liabilities		412	415
Long-Term Debt		$ 2,374	$ 1,928
Commitments and Contingencies (Note 13)
Common units		$ 3,747	$ 4,353
Subordinated units		3,839	4,439
Partners’ Capital:
Total partners' capital attributable to Enable Midstream Partners, LP Partners’ Capital		7,586	8,792
Noncontrolling interest		25	31
Total Partners’ Capital		7,611	8,823
Total Liabilities and Partners’ Capital		$ 11,201	$ 11,837
[1]	Short-term debt includes $432 million and $253 million of commercial paper as of September 30, 2015 and December 31, 2014, respectively.

Condensed Consolidated Balance5

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - shares	Sep. 30, 2015	Dec. 31, 2014
Common Units
Common and Subordinated units issued	214,534,491	214,417,908
Common units and Subordinated units outstanding	214,534,491	214,417,908
Subordinated Units
Common and Subordinated units issued	207,855,430	207,855,430
Common units and Subordinated units outstanding	207,855,430	207,855,430

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash Flows from Operating Activities:
Net (loss) income	$ (823)	$ 410
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation and amortization	233	205
Deferred income taxes	1	(1)
Impairments	1,105	1
Loss on sale/retirement of assets	2	4
Equity in earnings of equity method affiliates, net of distributions	5	0
Equity based compensation	7	9
Amortization of debt costs and discount (premium)	(2)	(1)
Changes in other assets and liabilities:
Accounts receivable, net	(37)	(11)
Accounts receivable—affiliated companies	2	0
Inventory	11	6
Gas imbalance assets	29	(25)
Other current assets	(1)	(2)
Other assets	(5)	10
Accounts payable	(56)	(91)
Accounts payable—affiliated companies	(26)	(5)
Gas imbalance liabilities	4	(1)
Other current liabilities	45	50
Other liabilities	(3)	3
Net cash provided by operating activities	491	561
Cash Flows from Investing Activities:
Capital expenditures	(654)	(586)
Acquisitions, net of cash acquired	(80)	0
Proceeds from sale of assets	1	0
Return of investment in equity method affiliates	11	198
Investment in equity method affiliates	(8)	(187)
Other, net	0	2
Net cash used in investing activities	(730)	(573)
Cash Flows from Financing Activities:
Repayment of long term debt	0	(1,500)
Proceeds from long term debt, net of issuance costs	450	1,635
Proceeds from revolving credit facility	275	115
Repayment of revolving credit facility	(275)	(487)
Increase in short term debt	179	95
Capital contributions from partners	0	464
Distributions to partners	(397)	(400)
Net cash provided by (used in) financing activities	232	(78)
Net Decrease in Cash and Cash Equivalents	(7)	(90)
Cash and Cash Equivalents at Beginning of Period	12	108
Cash and Cash Equivalents at End of Period	$ 5	$ 18

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Enable Midstream Partners, LP Partners' Capital (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Partners' Capital	Total Enable Midstream Partners, LP Partners’ Capital	Noncontrolling Interest	Common UnitsPartners' Capital	Subordinated UnitsPartners' Capital
Balance, beginning of period at Dec. 31, 2013	$ 8,181		$ 8,148	$ 33	$ 8,148	$ 0
Balance, beginning of period, units at Dec. 31, 2013					390	0
Changes in Partners' Capital
Net (loss) income	410		408	2	$ 290	$ 118
Issuance of IPO common units, units					25
Issuance of IPO common units	464		464		$ 464
Conversion to subordinated units, units					(208)	(208)
Conversion to subordinated units	0		0		$ (4,372)	$ 4,372
Issuance of common units upon interest acquisition of SESH					6
Issuance of common units upon interest acquisition of SESH	161		161		$ 161
Distributions to partners	(400)		(397)	(3)	$ (345)	$ (52)
Equity based compensation, units					1
Equity based compensation	10		10		$ 10
Balance, end of period, units at Sep. 30, 2014					214	208
Balance, end of period at Sep. 30, 2014	8,826		8,794	32	$ 4,356	$ 4,438
Balance, beginning of period at Dec. 31, 2014	8,823		8,792	31	$ 4,353	$ 4,439
Balance, beginning of period, units at Dec. 31, 2014					214	208
Changes in Partners' Capital
Net (loss) income	(823)		(817)	(6)	$ (412)	$ (405)
Issuance of common units upon interest acquisition of SESH	1	$ 1	1
Distributions to partners	(397)		(397)		(202)	$ (195)
Equity based compensation	7		7		$ 7
Balance, end of period, units at Sep. 30, 2015					214	208
Balance, end of period at Sep. 30, 2015	$ 7,611		$ 7,586	$ 25	$ 3,747	$ 3,839

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 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 services 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 Ark-La-Tex 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 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. As of September 30, 2015 , CenterPoint Energy held approximately 55.4% of the limited partner interests in the Partnership, or 94,151,707 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 June 29, 2015, the financial statements reflect a 49.90% interest in SESH. On June 12, 2015, CenterPoint Energy exercised its put right with respect to a 0.1% interest in SESH. Pursuant to the put right, on June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership in exchange for 25,341 common units representing limited partner interests in the Partnership. As of September 30, 2015 , the Partnership owned a 50% interest in SESH. See Note 7 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, 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 segments, see Note 15. Revenue Recognition The Partnership generates the majority of its revenues from midstream energy services, including natural gas gathering, processing, transportation and storage and crude oil gathering. The Partnership performs these services under various contractual arrangements, which include fee-based contract arrangements and arrangements pursuant to which it purchases and resells commodities in connection with providing the related service and earns a net margin for its fee. While the Partnership's transactions vary in form, the essential element of each transaction is the use of its assets to transport a product or provide a processed product to a customer. The Partnership reflects revenue as Product sales and Service revenue on the Condensed Consolidated Statements of Income as follows: Product sales : Product sales represent the sale of natural gas, NGLs, crude oil and condensate where the product is purchased and used in connection with providing the Partnership's midstream services. Service revenue: Service revenue represents all other revenue generated as a result of performing the Partnership's midstream services. Revenues for gathering, processing, and transportation and storage services for the Partnership are recorded each month based on the current month’s estimated volumes, contracted prices (considering current commodity prices), historical seasonal fluctuations and any known adjustments. The estimates are reversed in the following month, and customers are billed on actual volumes and contracted prices. Gas sales are calculated on current-month nominations and contracted prices. Revenues associated with the production of NGLs are estimated based on current-month estimated production and contracted prices. These amounts are also reversed in the following month, and the customers are billed on actual production and contracted prices. Estimated revenues are reflected in Accounts Receivable or Accounts Receivable-affiliated companies, as appropriate, on the Consolidated Balance Sheets and in Total Revenues on the Combined and Consolidated Statements of Income. The Partnership recognizes revenue from natural gas gathering, processing, transportation and storage and crude oil gathering services to third parties as services are provided. Revenue associated with NGLs is recognized when the production is sold. The Partnership records deferred revenue when it receives consideration from a third party before achieving certain criteria that must be met for revenue to be recognized in accordance with GAAP. Cost of natural gas and natural gas liquids represents cost of our natural gas and natural gas liquids purchased exclusive of depreciation and Operation and maintenance expenses and consists primarily of product and fuel costs. Operation and maintenance expense represents the cost of our service related revenues and consists primarily of labor expenses, lease costs, utility costs, insurance premiums and repairs and maintenance expenses. Any Operation and maintenance expenses associated with product sales are immaterial. 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 not 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. Fair Value - Monarch Acquisition On April 22, 2015, Enable entered into an agreement with Monarch Natural Gas, LLC, pursuant to which Enable agreed to acquire approximately 106 miles of gathering pipeline, approximately 5,000 horsepower of associated compression, right-of-ways and certain other midstream assets that provide natural gas gathering services in the Greater Granite Wash area of Texas. The transaction closed on May 1, 2015. The aggregate purchase price for this transaction was approximately $80 million , which was funded from cash generated from operations and borrowings under our Revolving Credit Facility. The acquisition was accounted for as a business combination. During the third quarter of 2015, the Partnership, with the assistance of a third-party valuation expert, finalized the purchase price allocation as of May 1, 2015. Purchase price allocation (in millions): Property, plant and equipment $ 51 Intangibles 10 Goodwill 19 Total $ 80 The Partnership recognized intangible assets related to customer relationships. The acquired intangible assets will be amortized on a straight-line basis over the estimated customer contract life of approximately 15 years. Goodwill recognized from the acquisition primarily relates to the value created from additional growth opportunities and greater operating leverage in the Anadarko Basin. See Note 6 for further information related to the Partnership's goodwill impairment. The Partnership incurred less than $1 million of acquisition costs associated with this transaction, which are included in Operation and maintenance expense in the Condensed Consolidated Statement of Income. 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.

New Accounting Pronouncements

New Accounting Pronouncements	9 Months Ended
	Sep. 30, 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. In August 2015, FASB issued ASU No. 2015-14, "Revenue from Contracts with Customers (Topic 606)—Deferral of the Effective Date," which deferred 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 and related disclosures. 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. As of September 30, 2015 and December 31, 2014 , the Partnership had unamortized debt expense of $18 million and $17 million , respectively, a portion of which would have been classified as a reduction of long-term debt in our condensed consolidated balance sheets had we adopted this standard in the third quarter of 2015. The Partnership does not expect a material impact on its results of operations upon adoption of ASU 2015-03. In August 2015, the FASB issued ASU No. 2015-15, "Interest—Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements—Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting." This ASU adds SEC paragraphs pursuant to the SEC Staff Announcement at the June 18, 2015, Emerging Issues Task Force meeting about the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements to this topic. Given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC staff would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Partnership does not expect a material impact on its results of operations upon adoption of ASU 2015-15. 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 and related disclosures. Simplifying the Measurement of Inventory In July 2015, the FASB issued ASU No. 2015-11, "Simplifying the Measurement of Inventory." Under this ASU, inventory will be measured at the “lower of cost and net realizable value,” and options that currently exist for “market value” will be eliminated. The ASU defines net realizable value as the “estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation.” No other changes were made to the current guidance on inventory measurement. ASU 2015-11 is effective for interim and annual periods beginning after December 15, 2016. Early application is permitted and should be applied prospectively. The Partnership is evaluating the provisions of this statement, including in which period to adopt this statement, and has not determined what impact the adoption of ASU 2015-11 will have on the Partnership's Consolidated Financial Statements and related disclosures. Simplifying the Accounting for Measurement-Period Adjustments In September 2015, the FASB issued ASU No. 2015-16, "Business Combinations—Simplifying the Accounting for Measurement-Period Adjustments." Under this ASU, acquirers are required to record, in the same period's financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. Acquirers are required to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. ASU 2015-16 is effective for interim and annual periods beginning after December 15, 2016. The amendments in this update should be applied prospectively to adjustments to provisional amounts that occur after the effective date with earlier application permitted for financial statements that have not been issued. The Partnership is currently evaluating the impact, if any, the adoption of this standard will have on our Consolidated Financial Statements and related disclosures.

Earnings Per Limited Partner Un

Earnings Per Limited Partner Unit	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	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 Nine Months Ended 2015 2014 2015 2014 (In millions, except per unit data) Net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Less general partner interest in net (loss) income — — — — Limited partner interest in net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Net (loss) income allocable to common units $ (499 ) $ 71 $ (414 ) $ 282 Net (loss) income allocable to subordinated units (486 ) 68 (403 ) 126 Limited partner interest in net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Basic and diluted weighted average number of outstanding limited partner units Common units 214 214 214 281 Subordinated units (1) 208 208 208 128 Total 422 422 422 409 Basic and diluted (loss) earnings per limited partner unit Common units $ (2.33 ) $ 0.33 $ (1.93 ) $ 1.00 Subordinated units (1) $ (2.34 ) $ 0.33 $ (1.94 ) $ 0.98 ____________________ (1) Basic and diluted earnings per subordinated unit reflect net (loss) 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 or nine months ended September 30, 2015 and 2014 .

Partners' Capital

Partners' Capital	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
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 September 30, 2015 (1) November 3, 2015 November 13, 2015 $ 0.318 $ 134 June 30, 2015 August 3, 2015 August 13, 2015 $ 0.316 $ 134 March 31, 2015 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 $0.318 per common unit cash distribution on October 22, 2015 , to be paid on November 13, 2015 , to unitholders of record at the close of business on November 3, 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

Intangible Assets, Net	9 Months Ended
	Sep. 30, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets, Net	Intangible Assets, Net The Partnership has $411 million in intangible assets associated with customer relationships due to the acquisition of Enogex and assets acquired from Monarch Natural Gas, LLC. The Partnership determined that intangible assets related to customer relationships have a weighted average useful life of 15 years. 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: September 30, December 31, 2014 (In millions) Customer relationships: Total intangible assets $ 411 $ 401 Accumulated amortization 65 45 Net intangible assets $ 346 $ 356 The Partnership recorded amortization expense of $7 million during each of the three months ended September 30, 2015 and 2014 , respectively, and $20 million during each of the nine months ended September 30, 2015 and 2014 , respectively. As discussed in Note 1, the Partnership acquired a gas gathering system from Monarch Natural Gas, LLC on May 1, 2015 and has allocated $10 million to intangible assets based upon the purchase price allocation.

Assessing Impairment of Long-li

Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill	9 Months Ended
	Sep. 30, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill	Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill Impairment of Long-lived Assets (including Intangible Assets) The Partnership periodically evaluates long-lived assets, including property, plant and equipment, and specifically identifiable intangibles other than goodwill, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted cash flows attributable to the assets, as compared to the carrying value of the assets. During each of the three and nine months ended September 30, 2015 , the Partnership recorded a $12 million impairment on jurisdictional pipelines in our transportation and storage segment, and a $6 million impairment to our Service Star business line, a component of our gathering and processing segment, which is included in Impairments on the Condensed Consolidated Statements of Income. The Partnership recorded no other material impairments to long-lived assets in the three and nine months ended September 30, 2015 or 2014 . Based upon review of forecasted undiscounted cash flows, none of the asset groups were at risk of failing step one of the impairment test. Further price declines, throughput declines, cost increases, regulatory or political environment changes, and other changes in market conditions could reduce forecast undiscounted cash flows. Impairment of Goodwill The goodwill associated with the gathering and processing reportable segment is primarily related to the acquisitions of Enable Oklahoma, Waskom and Monarch. The Partnership recognized $438 million of goodwill as a result of the acquisition of Enable Oklahoma, which occurred at the time of the formation of the Partnership in 2013. The $579 million of goodwill associated with the transportation and storage reportable segment is related to the original acquisitions of EGT and MRT in 1997 by predecessors of the Partnership. The Partnership tests its goodwill for impairment annually on October 1st, or more frequently if events or changes in circumstances indicate that the carrying value of goodwill may not be recoverable. Goodwill is assessed for impairment by comparing the fair value of the reporting unit with its book value, including goodwill. Subsequent to the completion of the October 1, 2014 annual test and previous interim assessment as of December 31, 2014, the crude oil and natural gas industry was impacted by further commodity price declines, which consequently resulted in decreased producer activity in certain regions in which the Partnership operates. Due to the continuing commodity price declines, the resulting decreases in forward commodity prices and forecasted producer activities, and an increase in the weighted average cost of capital, we determined that the impact on our forecasted discounted cash flows for our gathering and processing and transportation and storage reportable segments would be significantly reduced. As a result, when we performed the first step of our annual goodwill impairment analysis as of October 1, 2015, we determined that the carrying value of the gathering and processing and transportation and storage reportable segments exceeded fair value. We completed the second step of the goodwill impairment analysis by comparing the implied fair value of the reporting unit to the carrying amount of that goodwill and determined that goodwill was completely impaired in the amount of $1,087 million , which is included in Impairments on the Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2015 . The change in carrying amount of goodwill in each of our reportable segments is as follows: Gathering and Processing Transportation and Storage Total (In millions) Balance as of December 31, 2014 $ 489 $ 579 $ 1,068 Acquisition of Monarch 19 — 19 Goodwill Impairment (508 ) (579 ) (1,087 ) Balance as of September 30, 2015 $ — $ — $ —

Investment in Equity Method Aff

Investment in Equity Method Affiliates	9 Months Ended
	Sep. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in Equity Method Affiliates	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. For the period from May 30, 2014 through June 29, 2015, the Partnership held a 49.90% interest in SESH. On June 12, 2015, CenterPoint Energy exercised its put right with respect to its remaining 0.1% interest in SESH. Pursuant to the put right, on June 30, 2015, CenterPoint Energy contributed a 0.1% interest in SESH to the Partnership in exchange for 25,341 common units representing limited partner interests in the Partnership, which had a fair value of $1 million based upon the closing market price of the Partnership's common units. 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, or does not have the ability to exercise certain control rights, affiliates of Spectra Energy Corp could have the right to purchase our interest in SESH at fair market value. As of September 30, 2015 , the Partnership owned a 50% 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: Nine Months Ended 2015 2014 (In millions) Balance as of December 31 $ 348 $ 198 Interest acquisition of SESH 1 161 Return of investment from SESH refinancing — (198 ) Additional investment in SESH — 187 Equity in earnings of equity method affiliate 21 12 Contributions to equity method affiliate 8 2 Distributions from equity method affiliate (37 ) (13 ) Balance as of September 30 $ 341 $ 349 Equity in Earnings of Equity Method Affiliates: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) SESH $ 7 $ 5 $ 21 $ 12 Distributions from Equity Method Affiliates: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) SESH $ 10 $ 7 $ 37 $ 13 Summarized financial information of SESH is presented below: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Income Statements: Revenues $ 29 $ 27 $ 86 $ 80 Operating income 18 17 54 50 Net income 14 12 42 34

Debt

Debt	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Debt	Debt The following table presents the Partnership's outstanding debt as of September 30, 2015 and December 31, 2014 . September 30, December 31, (In millions) Commercial Paper $ 432 $ 253 Term Loan Facility 450 — 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 24 28 Total debt 3,169 2,544 Less amount classified as short-term debt (1) 432 253 Less Notes payable—affiliated companies 363 363 Total long-term debt $ 2,374 $ 1,928 ___________________ (1) Short-term debt includes $432 million and $253 million of commercial paper as of September 30, 2015 and December 31, 2014 , respectively. Revolving Credit Facility On June 18, 2015, the Partnership amended and restated its Revolving Credit Facility to, among other things, increase the borrowing capacity thereunder to $1.75 billion and extend its maturity date to June 18, 2020. As of September 30, 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. The Revolving Credit Facility provides that outstanding borrowings bear interest at the LIBOR and/or an alternate base rate, at the Partnership’s election, plus an applicable margin. The applicable margin is based on the Partnership’s applicable credit ratings. As of September 30, 2015 , the applicable margin for LIBOR-based borrowings under the Revolving Credit Facility was 1.50% based on the Partnership’s credit ratings. In addition, the Revolving Credit Facility requires the Partnership to pay a fee on unused commitments. The commitment fee is based on the Partnership’s applicable credit rating from the rating agencies. As of September 30, 2015 , the commitment fee under the Revolving Credit Facility was 0.20% per annum based on the Partnership’s credit ratings. The commitment fee is recorded as interest expense in the Partnership's Condensed Consolidated Statements of Income. 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. There was $432 million and $253 million outstanding under our commercial paper program as of September 30, 2015 and December 31, 2014 , respectively. Any reduction in our credit ratings could prevent us from accessing the commercial paper markets. Term Loan Agreement On July 31, 2015, the Partnership entered into a Term Loan Agreement dated as of July 31, 2015, providing for an unsecured three -year $450 million term loan facility (Term Loan Facility). The entire $450 million principal amount of the Term Loan Facility was borrowed by Enable on July 31, 2015. The Term Loan Facility contains an option, which may be exercised up to two times, to extend the term of the Term Loan Facility, in each case, for an additional one -year term. The Term Loan Facility provides an option to prepay, without penalty or premium, the amount outstanding, or any portion thereof, in a minimum amount of $1 million , or any multiple of $0.5 million in excess thereof. As of September 30, 2015 , there was $450 million outstanding under the Term Loan Facility. The Term Loan Facility provides that outstanding borrowings bear interest at the LIBOR and/or an alternate base rate, at the Partnership’s election, plus an applicable margin. The applicable margin is based on our applicable credit ratings. As of September 30, 2015 , the applicable margin for LIBOR-based borrowings under the term loan facility was 1.375% based on our credit ratings. Senior Notes In connection with the issuance of the 2019 Notes, 2024 Notes and 2044 Notes, the Partnership, CenterPoint Energy Resources Corp., as guarantor, and RBS Securities Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Credit Suisse Securities (USA) LLC, and RBC Capital Markets, LLC, as representatives of the initial purchasers, entered into a registration rights agreement whereby the Partnership and the guarantor agreed to file with the SEC a registration statement relating to a registered offer to exchange the 2019 Notes, 2024 Notes and 2044 Notes for new series of the Partnership's notes in the same aggregate principal amount as, and with terms substantially identical in all respects to, the 2019 Notes, 2024 Notes and 2044 Notes. The agreement provided for the accrual of additional interest if the Partnership did not complete an exchange offer by October 9, 2015. Because an exchange offer was not consummated by October 9, 2015 , additional interest began accruing on the 2019 Notes, 2024 Notes and 2044 Notes on October 10, 2015, at a rate of 0.25% per year until the first 90-day period after such date. The amount of additional interest will increase by an additional 0.25% per year for each subsequent 90-day period during which the exchange offer registration statement is not declared effective or the exchange offer is not completed, up to a maximum of 1.00% per year. Financing Costs Unamortized debt expense of $18 million and $17 million as of September 30, 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 $24 million and $28 million at September 30, 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 September 30, 2015 , the Partnership and Enable Oklahoma were in compliance with all of their debt agreements, including financial covenants.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	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 September 30, 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 September 30, 2015 and December 31, 2014 : September 30, 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) $ 17 $ 3 $ — $ — Significant other observable inputs (Level 2) 1 — 10 $ 12 Unobservable inputs (Level 3) 11 1 — $ — Total fair value 29 4 10 $ 12 Netting adjustments (4 ) (4 ) — $ — Total $ 25 $ — $ 10 $ 12 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 September 30, 2015 and December 31, 2014 . (2) Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $6 million and $4 million at September 30, 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 $5 million and $1 million at September 30, 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, 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 September 30, 2015 and December 31, 2014 . September 30, 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 $ 361 $ 363 $ 362 Revolving Credit Facility (Level 2) (1) — — — — Term Loan Facility (Level 2) 450 450 — — Enable Oklahoma Senior Notes (Level 2) 275 275 279 282 Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2) 1,649 1,442 1,649 1,592 ___________________ (1) Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $432 million and $253 million of commercial paper was outstanding as of September 30, 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 September 30, 2015 and December 31, 2014 , no material fair value adjustments or fair value measurements were required for these non-financial assets or liabilities.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	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 September 30, 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 September 30, 2015 and December 31, 2014 , the Partnership had the following derivative instruments that were not designated as hedging instruments for accounting purposes: September 30, 2015 December 31, 2014 Gross Notional Volume Purchases Sales Purchases Sales Natural gas— TBtu (1) Physical purchases/sales 2 64 4 32 Financial fixed futures/swaps 2 32 5 35 Financial basis futures/swaps 3 41 7 54 Condensate— MBbl (2) Financial Futures/swaps — 1 — 12 Natural gas liquids— MBbl (3) Financial Futures/swaps — 1 — — ____________________ (1) As of September 30, 2015 , 90.6% of the natural gas contracts had durations of one year or less, 9.2% had durations of more than one year and less than two years and 0.2% 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 September 30, 2015 , 88.9% of the condensate contracts had durations of one year or less and 11.1% 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 September 30, 2015 , 89.3% of the natural gas liquids contracts had durations of one year or less and 10.7% had durations of more than one year and less than two years. Balance Sheet Presentation Related to Derivative Instruments The fair value of the derivative instruments that are presented in the Partnership’s Condensed Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014 that were not designated as hedging instruments for accounting purposes are as follows: September 30, 2015 December 31, 2014 Fair Value Instrument Balance Sheet Location Assets Liabilities Assets Liabilities (In millions) Natural gas Financial futures/swaps Other Current $ 17 $ 3 $ 34 $ 4 Physical purchases/sales Other Current 1 — 1 — Condensate Financial futures/swaps Other Current 2 — 5 — Natural gas liquids Financial Futures/swaps Other Current 9 1 — — Total gross derivatives (1) $ 29 $ 4 $ 40 $ 4 _____________________ (1) See Note 9 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of September 30, 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 Statements of Income for the three and nine months ended September 30, 2015 . Amounts Recognized in Income Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Natural gas financial futures/swaps gains (losses) $ 10 $ 3 $ 13 $ 4 Natural gas physical purchases/sales gains (losses) (1 ) (1 ) (5 ) (1 ) Condensate financial futures/swaps gains (losses) 11 3 8 2 Natural gas liquids financial futures/swaps gains (losses) 1 — 7 — Total $ 21 $ 5 $ 23 $ 5 For derivatives not designated as hedges in the tables above, amounts recognized in income for the periods ended September 30, 2015 and 2014 , if any, are reported in Product Sales. 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 September 30, 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 September 30, 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.

Supplemental Disclosure of Cash

Supplemental Disclosure of Cash Flow Information	9 Months Ended
	Sep. 30, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Disclosure of Cash Flow Information	Supplemental Disclosure of Cash Flow Information The following table provides information regarding supplemental cash flow information: Nine Months Ended 2015 2014 (In millions) Supplemental Disclosure of Cash Flow Information: Cash Payments: Interest, net of capitalized interest $ 61 $ 53 Income taxes, net of refunds 2 1 Non-cash transactions: Accounts payable related to capital expenditures 66 4 Issuance of common units upon interest acquisition of SESH (Note 7) 1 161

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	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 6% and 5% of revenues during the three months ended September 30, 2015 and 2014 , respectively, and 7% and 5% of revenues during the nine months ended September 30, 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 Nine Months Ended 2015 2014 2015 2014 (In millions) Gas transportation and storage service revenue - CenterPoint Energy $ 23 $ 22 $ 79 $ 82 Natural gas product sales - CenterPoint Energy — 1 7 17 Gas transportation and storage service revenue - OGE Energy (1) 10 9 28 31 Natural gas product sales - OGE Energy (1) 3 5 7 10 Total revenues - affiliated companies $ 36 $ 37 $ 121 $ 140 ____________________ (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 Statements 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 Nine Months Ended 2015 2014 2015 2014 (In millions) Cost of natural gas purchases - CenterPoint Energy $ 1 $ — $ 2 $ 2 Cost of natural gas purchases - OGE Energy 5 8 12 14 Total cost of natural gas purchases - affiliated companies $ 6 $ 8 $ 14 $ 16 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 $15 million and $11 million , respectively. Amounts charged to the Partnership by affiliates for seconded employees and corporate services, included primarily in Operation and maintenance expenses in Partnership’s Condensed Consolidated Statements of Income are as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Seconded Employee Costs - CenterPoint Energy $ — $ 32 $ — $ 101 Corporate Services - CenterPoint Energy 5 6 12 23 Seconded Employee Costs - OGE Energy 12 25 30 78 Corporate Services - OGE Energy 2 3 8 13 Total corporate services and seconded employees expense $ 19 $ 66 $ 50 $ 215 The Partnership has outstanding long-term notes payable—affiliated companies to CenterPoint Energy at both September 30, 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 September 30, 2015 and 2014 , respectively, and $6 million during each of the nine months ended September 30, 2015 and 2014 , respectively.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 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

Equity Based Compensation	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity Based Compensation	Equity Based Compensation The following table summarizes the Partnership’s compensation expense for the three and nine months ended September 30, 2015 and 2014 related to performance units, restricted units, and phantom units for the Partnership's employees. Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Performance units $ 1 $ 1 $ 3 $ 1 Restricted units 2 3 5 8 Phantom units — 1 1 1 Total compensation expense $ 3 $ 5 $ 9 $ 10 Units Outstanding The Partnership periodically grants performance units, restricted units, and phantom units to certain employees. Under the Enable Midstream Partners, LP Long Term Incentive Plan, the Partnership granted performance units and restricted units to certain employees in the second quarter of 2015. A summary of the activity for the Partnership's performance units, restricted units, and phantom units applicable to the Partnership’s employees at September 30, 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) 501,474 279,677 — Vested (1,254 ) (375,504 ) (90,000 ) Forfeited (222,389 ) (126,278 ) (2,000 ) Units Outstanding at September 30, 2015 830,412 $ 10 615,963 $ 8 6,718 $ — Units Fully Vested at September 30, 2015 2,799 90,500 _____________________ (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. September 30, 2015 Unrecognized Compensation Cost (In millions) Weighted Average to be Recognized (In years) Performance Units $ 11 2.3 Restricted Units 10 1.9 Phantom Units — 0.1 Total $ 21 As of September 30, 2015 , there were 11,056,759 units available for issuance under the long term incentive plan.

Reportable Segments

Reportable Segments	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Reportable 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 are as follows: Three Months Ended September 30, 2015 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 456 $ 299 $ (109 ) $ 646 Cost of natural gas and natural gas liquids 235 161 (109 ) 287 Operation and maintenance 75 55 — 130 Depreciation and amortization 53 31 — 84 Impairments 514 591 — 1,105 Taxes other than income tax 8 7 — 15 Operating loss $ (429 ) $ (546 ) $ — $ (975 ) Total assets $ 7,441 $ 4,857 $ (1,097 ) $ 11,201 Capital expenditures $ 167 $ 31 $ — $ 198 Three Months Ended September 30, 2014 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 604 $ 341 $ (142 ) $ 803 Cost of natural gas and natural gas liquids 382 198 (141 ) 439 Operation and maintenance 76 53 (1 ) 128 Depreciation and amortization 41 28 — 69 Impairments 1 — — 1 Taxes other than income tax 8 6 — 14 Operating income $ 96 $ 56 $ — $ 152 Total assets as of December 31, 2014 $ 8,356 $ 5,493 $ (2,012 ) $ 11,837 Capital expenditures $ 227 $ 25 $ (4 ) $ 248 _____________________ (1) Transportation and Storage recorded equity income of $7 million and $5 million for the three months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015 , the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH. Nine Months Ended September 30, 2015 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 1,279 $ 875 $ (302 ) $ 1,852 Cost of natural gas and natural gas liquids 698 459 (301 ) 856 Operation and maintenance 229 163 (1 ) 391 Depreciation and amortization 141 92 — 233 Impairments 514 591 — 1,105 Taxes other than income tax 23 22 — 45 Operating loss $ (326 ) $ (452 ) $ — $ (778 ) Total assets $ 7,441 $ 4,857 $ (1,097 ) $ 11,201 Capital expenditures (2) $ 657 $ 77 $ — $ 734 Nine Months Ended September 30, 2014 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 1,882 $ 1,219 $ (469 ) $ 2,632 Cost of natural gas and natural gas liquids 1,250 768 (468 ) 1,550 Operation and maintenance 219 165 (1 ) 383 Depreciation and amortization 118 87 — 205 Impairments 1 — — 1 Taxes other than income tax 18 23 — 41 Operating income $ 276 $ 176 $ — $ 452 Total assets as of December 31, 2014 $ 8,356 $ 5,493 $ (2,012 ) $ 11,837 Capital expenditures $ 522 $ 69 $ (5 ) $ 586 _____________________ (1) Transportation and Storage recorded equity income of $21 million and $12 million for the nine months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015 , the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH. (2) As discussed in Note 1, the Partnership acquired a gas gathering system for $80 million from Monarch Natural Gas, LLC on May 1, 2015.

Summary of Significant Accoun23

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 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 services 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 Ark-La-Tex 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 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. As of September 30, 2015 , CenterPoint Energy held approximately 55.4% of the limited partner interests in the Partnership, or 94,151,707 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 June 29, 2015, the financial statements reflect a 49.90% interest in SESH. On June 12, 2015, CenterPoint Energy exercised its put right with respect to a 0.1% interest in SESH. Pursuant to the put right, on June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership in exchange for 25,341 common units representing limited partner interests in the Partnership. As of September 30, 2015 , the Partnership owned a 50% interest in SESH. See Note 7 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, 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.
Revenue Recognition	Revenue Recognition The Partnership generates the majority of its revenues from midstream energy services, including natural gas gathering, processing, transportation and storage and crude oil gathering. The Partnership performs these services under various contractual arrangements, which include fee-based contract arrangements and arrangements pursuant to which it purchases and resells commodities in connection with providing the related service and earns a net margin for its fee. While the Partnership's transactions vary in form, the essential element of each transaction is the use of its assets to transport a product or provide a processed product to a customer. The Partnership reflects revenue as Product sales and Service revenue on the Condensed Consolidated Statements of Income as follows: Product sales : Product sales represent the sale of natural gas, NGLs, crude oil and condensate where the product is purchased and used in connection with providing the Partnership's midstream services. Service revenue: Service revenue represents all other revenue generated as a result of performing the Partnership's midstream services. Revenues for gathering, processing, and transportation and storage services for the Partnership are recorded each month based on the current month’s estimated volumes, contracted prices (considering current commodity prices), historical seasonal fluctuations and any known adjustments. The estimates are reversed in the following month, and customers are billed on actual volumes and contracted prices. Gas sales are calculated on current-month nominations and contracted prices. Revenues associated with the production of NGLs are estimated based on current-month estimated production and contracted prices. These amounts are also reversed in the following month, and the customers are billed on actual production and contracted prices. Estimated revenues are reflected in Accounts Receivable or Accounts Receivable-affiliated companies, as appropriate, on the Consolidated Balance Sheets and in Total Revenues on the Combined and Consolidated Statements of Income. The Partnership recognizes revenue from natural gas gathering, processing, transportation and storage and crude oil gathering services to third parties as services are provided. Revenue associated with NGLs is recognized when the production is sold. The Partnership records deferred revenue when it receives consideration from a third party before achieving certain criteria that must be met for revenue to be recognized in accordance with GAAP. Cost of natural gas and natural gas liquids represents cost of our natural gas and natural gas liquids purchased exclusive of depreciation and Operation and maintenance expenses and consists primarily of product and fuel costs. Operation and maintenance expense represents the cost of our service related revenues and consists primarily of labor expenses, lease costs, utility costs, insurance premiums and repairs and maintenance expenses. Any Operation and maintenance expenses associated with product sales are immaterial.
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 Taxes	Income Taxes As a limited partnership, the Partnership’s earnings are not 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.
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. In August 2015, FASB issued ASU No. 2015-14, "Revenue from Contracts with Customers (Topic 606)—Deferral of the Effective Date," which deferred 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 and related disclosures. 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. As of September 30, 2015 and December 31, 2014 , the Partnership had unamortized debt expense of $18 million and $17 million , respectively, a portion of which would have been classified as a reduction of long-term debt in our condensed consolidated balance sheets had we adopted this standard in the third quarter of 2015. The Partnership does not expect a material impact on its results of operations upon adoption of ASU 2015-03. In August 2015, the FASB issued ASU No. 2015-15, "Interest—Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements—Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting." This ASU adds SEC paragraphs pursuant to the SEC Staff Announcement at the June 18, 2015, Emerging Issues Task Force meeting about the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements to this topic. Given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC staff would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Partnership does not expect a material impact on its results of operations upon adoption of ASU 2015-15. 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 and related disclosures. Simplifying the Measurement of Inventory In July 2015, the FASB issued ASU No. 2015-11, "Simplifying the Measurement of Inventory." Under this ASU, inventory will be measured at the “lower of cost and net realizable value,” and options that currently exist for “market value” will be eliminated. The ASU defines net realizable value as the “estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation.” No other changes were made to the current guidance on inventory measurement. ASU 2015-11 is effective for interim and annual periods beginning after December 15, 2016. Early application is permitted and should be applied prospectively. The Partnership is evaluating the provisions of this statement, including in which period to adopt this statement, and has not determined what impact the adoption of ASU 2015-11 will have on the Partnership's Consolidated Financial Statements and related disclosures. Simplifying the Accounting for Measurement-Period Adjustments In September 2015, the FASB issued ASU No. 2015-16, "Business Combinations—Simplifying the Accounting for Measurement-Period Adjustments." Under this ASU, acquirers are required to record, in the same period's financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. Acquirers are required to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. ASU 2015-16 is effective for interim and annual periods beginning after December 15, 2016. The amendments in this update should be applied prospectively to adjustments to provisional amounts that occur after the effective date with earlier application permitted for financial statements that have not been issued. The Partnership is currently evaluating the impact, if any, the adoption of this standard will have on our Consolidated Financial Statements and related disclosures.

Summary of Significant Accoun24

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of purchase price allocation	he Partnership, with the assistance of a third-party valuation expert, finalized the purchase price allocation as of May 1, 2015. Purchase price allocation (in millions): Property, plant and equipment $ 51 Intangibles 10 Goodwill 19 Total $ 80

Earnings Per Limited Partner 25

Earnings Per Limited Partner Unit (Tables)	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Schedule Of Earnings Per Unit For Common And Subordinated Limited Partner Units	The following table illustrates the Partnership’s calculation of earnings per unit for common and subordinated limited partner units: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions, except per unit data) Net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Less general partner interest in net (loss) income — — — — Limited partner interest in net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Net (loss) income allocable to common units $ (499 ) $ 71 $ (414 ) $ 282 Net (loss) income allocable to subordinated units (486 ) 68 (403 ) 126 Limited partner interest in net (loss) income attributable to Enable Midstream Partners, LP $ (985 ) $ 139 $ (817 ) $ 408 Basic and diluted weighted average number of outstanding limited partner units Common units 214 214 214 281 Subordinated units (1) 208 208 208 128 Total 422 422 422 409 Basic and diluted (loss) earnings per limited partner unit Common units $ (2.33 ) $ 0.33 $ (1.93 ) $ 1.00 Subordinated units (1) $ (2.34 ) $ 0.33 $ (1.94 ) $ 0.98 ____________________ (1) Basic and diluted earnings per subordinated unit reflect net (loss) income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

Partners' Capital (Tables)

Partners' Capital (Tables)	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Schedule Of Equity Transactions With Limited Partner	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 September 30, 2015 (1) November 3, 2015 November 13, 2015 $ 0.318 $ 134 June 30, 2015 August 3, 2015 August 13, 2015 $ 0.316 $ 134 March 31, 2015 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 $0.318 per common unit cash distribution on October 22, 2015 , to be paid on November 13, 2015 , to unitholders of record at the close of business on November 3, 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)

Intangible Assets, Net (Tables)	9 Months Ended
	Sep. 30, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	Intangible assets consist of the following: September 30, December 31, 2014 (In millions) Customer relationships: Total intangible assets $ 411 $ 401 Accumulated amortization 65 45 Net intangible assets $ 346 $ 356

Assessing Impairment of Long-28

Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill (Tables)	9 Months Ended
	Sep. 30, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of the change in carrying amount of goodwill	The change in carrying amount of goodwill in each of our reportable segments is as follows: Gathering and Processing Transportation and Storage Total (In millions) Balance as of December 31, 2014 $ 489 $ 579 $ 1,068 Acquisition of Monarch 19 — 19 Goodwill Impairment (508 ) (579 ) (1,087 ) Balance as of September 30, 2015 $ — $ — $ —

Investment in Unconsolidated Af

Investment in Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Investments Detail	Investment in Equity Method Affiliates: Nine Months Ended 2015 2014 (In millions) Balance as of December 31 $ 348 $ 198 Interest acquisition of SESH 1 161 Return of investment from SESH refinancing — (198 ) Additional investment in SESH — 187 Equity in earnings of equity method affiliate 21 12 Contributions to equity method affiliate 8 2 Distributions from equity method affiliate (37 ) (13 ) Balance as of September 30 $ 341 $ 349 Equity in Earnings of Equity Method Affiliates: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) SESH $ 7 $ 5 $ 21 $ 12 Distributions from Equity Method Affiliates: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) SESH $ 10 $ 7 $ 37 $ 13 Summarized financial information of SESH is presented below: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Income Statements: Revenues $ 29 $ 27 $ 86 $ 80 Operating income 18 17 54 50 Net income 14 12 42 34

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Schedule of Debt	The following table presents the Partnership's outstanding debt as of September 30, 2015 and December 31, 2014 . September 30, December 31, (In millions) Commercial Paper $ 432 $ 253 Term Loan Facility 450 — 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 24 28 Total debt 3,169 2,544 Less amount classified as short-term debt (1) 432 253 Less Notes payable—affiliated companies 363 363 Total long-term debt $ 2,374 $ 1,928 ___________________ (1) Short-term debt includes $432 million and $253 million of commercial paper as of September 30, 2015 and December 31, 2014 , respectively.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2015 and December 31, 2014 : September 30, 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) $ 17 $ 3 $ — $ — Significant other observable inputs (Level 2) 1 — 10 $ 12 Unobservable inputs (Level 3) 11 1 — $ — Total fair value 29 4 10 $ 12 Netting adjustments (4 ) (4 ) — $ — Total $ 25 $ — $ 10 $ 12 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 September 30, 2015 and December 31, 2014 . (2) Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $6 million and $4 million at September 30, 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 $5 million and $1 million at September 30, 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 September 30, 2015 and December 31, 2014 . September 30, 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 $ 361 $ 363 $ 362 Revolving Credit Facility (Level 2) (1) — — — — Term Loan Facility (Level 2) 450 450 — — Enable Oklahoma Senior Notes (Level 2) 275 275 279 282 Enable Midstream Partners, LP 2019, 2024 and 2044 Notes (Level 2) 1,649 1,442 1,649 1,592 ___________________ (1) Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $432 million and $253 million of commercial paper was outstanding as of September 30, 2015 and December 31, 2014 , respectively.

Derivative Instruments and He32

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of September 30, 2015 and December 31, 2014 , the Partnership had the following derivative instruments that were not designated as hedging instruments for accounting purposes: September 30, 2015 December 31, 2014 Gross Notional Volume Purchases Sales Purchases Sales Natural gas— TBtu (1) Physical purchases/sales 2 64 4 32 Financial fixed futures/swaps 2 32 5 35 Financial basis futures/swaps 3 41 7 54 Condensate— MBbl (2) Financial Futures/swaps — 1 — 12 Natural gas liquids— MBbl (3) Financial Futures/swaps — 1 — — ____________________ (1) As of September 30, 2015 , 90.6% of the natural gas contracts had durations of one year or less, 9.2% had durations of more than one year and less than two years and 0.2% 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 September 30, 2015 , 88.9% of the condensate contracts had durations of one year or less and 11.1% 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 September 30, 2015 , 89.3% of the natural gas liquids contracts had durations of one year or less and 10.7% had durations of more than one year and less than two years.
Schedule of Derivative Assets at Fair Value	The fair value of the derivative instruments that are presented in the Partnership’s Condensed Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014 that were not designated as hedging instruments for accounting purposes are as follows: September 30, 2015 December 31, 2014 Fair Value Instrument Balance Sheet Location Assets Liabilities Assets Liabilities (In millions) Natural gas Financial futures/swaps Other Current $ 17 $ 3 $ 34 $ 4 Physical purchases/sales Other Current 1 — 1 — Condensate Financial futures/swaps Other Current 2 — 5 — Natural gas liquids Financial Futures/swaps Other Current 9 1 — — Total gross derivatives (1) $ 29 $ 4 $ 40 $ 4 _____________________ (1) See Note 9 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of September 30, 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 Statements of Income for the three and nine months ended September 30, 2015 . Amounts Recognized in Income Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Natural gas financial futures/swaps gains (losses) $ 10 $ 3 $ 13 $ 4 Natural gas physical purchases/sales gains (losses) (1 ) (1 ) (5 ) (1 ) Condensate financial futures/swaps gains (losses) 11 3 8 2 Natural gas liquids financial futures/swaps gains (losses) 1 — 7 — Total $ 21 $ 5 $ 23 $ 5

Supplemental Disclosure of Ca33

Supplemental Disclosure of Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2015
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides information regarding supplemental cash flow information: Nine Months Ended 2015 2014 (In millions) Supplemental Disclosure of Cash Flow Information: Cash Payments: Interest, net of capitalized interest $ 61 $ 53 Income taxes, net of refunds 2 1 Non-cash transactions: Accounts payable related to capital expenditures 66 4 Issuance of common units upon interest acquisition of SESH (Note 7) 1 161

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
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 Nine Months Ended 2015 2014 2015 2014 (In millions) Gas transportation and storage service revenue - CenterPoint Energy $ 23 $ 22 $ 79 $ 82 Natural gas product sales - CenterPoint Energy — 1 7 17 Gas transportation and storage service revenue - OGE Energy (1) 10 9 28 31 Natural gas product sales - OGE Energy (1) 3 5 7 10 Total revenues - affiliated companies $ 36 $ 37 $ 121 $ 140 ____________________ (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 Statements 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.
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 Nine Months Ended 2015 2014 2015 2014 (In millions) Cost of natural gas purchases - CenterPoint Energy $ 1 $ — $ 2 $ 2 Cost of natural gas purchases - OGE Energy 5 8 12 14 Total cost of natural gas purchases - affiliated companies $ 6 $ 8 $ 14 $ 16
Schedule of Amounts Charged to Partnership by Related Parties	Amounts charged to the Partnership by affiliates for seconded employees and corporate services, included primarily in Operation and maintenance expenses in Partnership’s Condensed Consolidated Statements of Income are as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Seconded Employee Costs - CenterPoint Energy $ — $ 32 $ — $ 101 Corporate Services - CenterPoint Energy 5 6 12 23 Seconded Employee Costs - OGE Energy 12 25 30 78 Corporate Services - OGE Energy 2 3 8 13 Total corporate services and seconded employees expense $ 19 $ 66 $ 50 $ 215

Equity Based Compensation (Tabl

Equity Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	The following table summarizes the Partnership’s compensation expense for the three and nine months ended September 30, 2015 and 2014 related to performance units, restricted units, and phantom units for the Partnership's employees. Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Performance units $ 1 $ 1 $ 3 $ 1 Restricted units 2 3 5 8 Phantom units — 1 1 1 Total compensation expense $ 3 $ 5 $ 9 $ 10
Schedule of Share-based Compensation, Activity	A summary of the activity for the Partnership's performance units, restricted units, and phantom units applicable to the Partnership’s employees at September 30, 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) 501,474 279,677 — Vested (1,254 ) (375,504 ) (90,000 ) Forfeited (222,389 ) (126,278 ) (2,000 ) Units Outstanding at September 30, 2015 830,412 $ 10 615,963 $ 8 6,718 $ — Units Fully Vested at September 30, 2015 2,799 90,500 _____________________ (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.
Schedule of Unrecognized Compensation Cost, Nonvested Awards	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. September 30, 2015 Unrecognized Compensation Cost (In millions) Weighted Average to be Recognized (In years) Performance Units $ 11 2.3 Restricted Units 10 1.9 Phantom Units — 0.1 Total $ 21

Reportable Segments (Tables)

Reportable Segments (Tables)	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Schedule of Financial Data for Business Segments and Services	Financial data for reportable segments are as follows: Three Months Ended September 30, 2015 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 456 $ 299 $ (109 ) $ 646 Cost of natural gas and natural gas liquids 235 161 (109 ) 287 Operation and maintenance 75 55 — 130 Depreciation and amortization 53 31 — 84 Impairments 514 591 — 1,105 Taxes other than income tax 8 7 — 15 Operating loss $ (429 ) $ (546 ) $ — $ (975 ) Total assets $ 7,441 $ 4,857 $ (1,097 ) $ 11,201 Capital expenditures $ 167 $ 31 $ — $ 198 Three Months Ended September 30, 2014 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 604 $ 341 $ (142 ) $ 803 Cost of natural gas and natural gas liquids 382 198 (141 ) 439 Operation and maintenance 76 53 (1 ) 128 Depreciation and amortization 41 28 — 69 Impairments 1 — — 1 Taxes other than income tax 8 6 — 14 Operating income $ 96 $ 56 $ — $ 152 Total assets as of December 31, 2014 $ 8,356 $ 5,493 $ (2,012 ) $ 11,837 Capital expenditures $ 227 $ 25 $ (4 ) $ 248 _____________________ (1) Transportation and Storage recorded equity income of $7 million and $5 million for the three months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015 , the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH. Nine Months Ended September 30, 2015 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 1,279 $ 875 $ (302 ) $ 1,852 Cost of natural gas and natural gas liquids 698 459 (301 ) 856 Operation and maintenance 229 163 (1 ) 391 Depreciation and amortization 141 92 — 233 Impairments 514 591 — 1,105 Taxes other than income tax 23 22 — 45 Operating loss $ (326 ) $ (452 ) $ — $ (778 ) Total assets $ 7,441 $ 4,857 $ (1,097 ) $ 11,201 Capital expenditures (2) $ 657 $ 77 $ — $ 734 Nine Months Ended September 30, 2014 Gathering and Processing Transportation and Storage (1) Eliminations Total (In millions) Total revenues $ 1,882 $ 1,219 $ (469 ) $ 2,632 Cost of natural gas and natural gas liquids 1,250 768 (468 ) 1,550 Operation and maintenance 219 165 (1 ) 383 Depreciation and amortization 118 87 — 205 Impairments 1 — — 1 Taxes other than income tax 18 23 — 41 Operating income $ 276 $ 176 $ — $ 452 Total assets as of December 31, 2014 $ 8,356 $ 5,493 $ (2,012 ) $ 11,837 Capital expenditures $ 522 $ 69 $ (5 ) $ 586 _____________________ (1) Transportation and Storage recorded equity income of $21 million and $12 million for the nine months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015 , the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH. (2) As discussed in Note 1, the Partnership acquired a gas gathering system for $80 million from Monarch Natural Gas, LLC on May 1, 2015.

Summary of Significant Accoun37

Summary of Significant Accounting Policies - Narrative (Details) $ / shares in Units, hp in Thousands	Jun. 12, 2015	May. 01, 2015USD ($)	Jul. 25, 2014	Apr. 16, 2014USD ($)$ / sharesshares	Mar. 25, 2014	Sep. 30, 2014	May. 29, 2014	Sep. 30, 2015USD ($)statesegmentshares	Jun. 29, 2015	Apr. 22, 2015mihp
Number of reportable segments | segment								2
Number of states | state								5
Conversion ratio					1.279082616
Operation and Maintenance Expense
Acquisition costs (less than $1 million) | $								$ 1,000,000
Customer Relationships
Estimated customer contract life								15 years
Gas Gathering and Processing Equipment
Number of miles of gathering pipeline | mi										106
Compression Horsepower | hp										5
Acquisition | $		$ 80,000,000
SESH
Limited partner ownership interest, exercisable as early as May 2014						24.95%	24.95%
Ownership percentage								50.00%
SESH | Put Option
Limited partner ownership interest			49.90%						49.90%
CenterPoint
Percentage share of management rights								50.00%
Percentage share of incentive distribution rights								40.00%
Limited partner ownership interest								55.40%
OGE Energy
Percentage share of management rights								50.00%
Percentage share of incentive distribution rights								60.00%
Limited partner ownership interest								26.30%
SESH | SESH | Put Option
Limited partner ownership interest, exercisable as early as May 2015	0.10%
Limited partner units that may be issued, exercisable as early as May 2015								25,341
Common Units | CenterPoint
Units outstanding								94,151,707
Common Units | OGE Energy
Units outstanding								42,832,291
Common Units | IPO
Common units issued during period (in shares)				25,000,000
Net proceeds from sale of common units, net of underwriting discounts, commissions, and other related expenses | $				$ 464,000,000
Initial public offering price (in dollars per share) | $ / shares				$ 20
Common Units | IPO | CenterPoint
Conversion of stock, common units converted (in shares)				139,704,916
Common Units | IPO | OGE Energy
Conversion of stock, common units converted (in shares)				68,150,514
Subordinated Units | CenterPoint
Units outstanding								139,704,916
Subordinated Units | OGE Energy
Units outstanding								68,150,514

Summary of Significant Accoun38

Summary of Significant Accounting Policies - Schedule of Purchase Price Allocation (Details) - USD ($) $ in Millions	Sep. 30, 2015	May. 01, 2015	Dec. 31, 2014
Business Acquisition [Line Items]
Goodwill	$ 0		$ 1,068
Monarch Natural Gas, LLC
Business Acquisition [Line Items]
Property, plant and equipment		$ 51
Intangibles		10
Goodwill		19
Total		$ 80

New Accounting Pronouncements (

New Accounting Pronouncements (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Other Assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Unamortized debt expense	$ 18	$ 17

Earnings Per Limited Partner 40

Earnings Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net (loss) income attributable to Enable Midstream Partners, LP		$ (985)	$ 139	$ (817)	$ 408
Less general partner interest in net (loss) income		0	0	0	0
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (985)	$ 139	$ (817)	$ 408
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	422	422	409
Basic and diluted (loss) earnings per limited partner unit
Dilutive effect of unit-based awards				$ 0	$ 0
Common Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (499)	$ 71	$ (414)	$ 282
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	214	214	281
Basic and diluted (loss) earnings per limited partner unit
Basic and diluted earnings per unit (in dollars per unit)		$ (2.33)	$ 0.33	$ (1.93)	$ 1
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Limited partners' interest in net (loss) income attributable to Enable Midstream Partners, LP (Note 3)		$ (486)	$ 68	$ (403)	$ 126
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	208	208	128
Basic and diluted (loss) earnings per limited partner unit
Basic and diluted earnings per unit (in dollars per unit)	[1]	$ (2.34)	$ 0.33	$ (1.94)	$ 0.98
[1]	Basic and diluted earnings per subordinated unit reflect net (loss) income attributable to the Partnership for periods subsequent to its Offering, as no subordinated units were outstanding prior to this date.

Partners' Capital Cash Distribu

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

Nov. 13, 2015

Nov. 03, 2015

Oct. 22, 2015

Aug. 13, 2015

Aug. 03, 2015

May. 15, 2015

May. 05, 2015

Feb. 13, 2015

Feb. 04, 2015

Nov. 14, 2014

Nov. 04, 2014

Aug. 14, 2014

[1]

Aug. 05, 2014

[1]

Distribution Made to Limited Partner [Line Items]

Record Date

Aug. 3, 2015

May 5, 2015

Feb. 4, 2015

Nov. 4, 2014

Aug. 4, 2014

Payment Date

Aug. 13, 2015

May 15, 2015

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

Cash Distribution

Distribution Made to Limited Partner [Line Items]

Per unit distribution, paid (per common unit)

$ 0.316

$ 0.3125

$ 0.30875

$ 0.3025

$ 0.2464

Distribution made to unitholders

$ 134

$ 132

$ 130

$ 128

$ 104

Subsequent Event

Distribution Made to Limited Partner [Line Items]

Record Date

[2]

Nov. 3, 2015

Subsequent Event | Cash Distribution

Distribution Made to Limited Partner [Line Items]

Per common unit cash distribution declared

$ 0.318

Subsequent Event | Scenario, Forecast

Distribution Made to Limited Partner [Line Items]

Payment Date

[2]

Nov. 13, 2015

Subsequent Event | Scenario, Forecast | Cash Distribution

Distribution Made to Limited Partner [Line Items]

Per unit distribution, paid (per common unit)

[2]

$ 0.318

Distribution made to unitholders

[2]

$ 134

[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 $0.318 per common unit cash distribution on October 22, 2015, to be paid on November 13, 2015, to unitholders of record at the close of business on November 3, 2015.

Partners' Capital Textual (Deta

Partners' Capital Textual (Details) - USD ($) $ / shares in Units, $ in Millions	Aug. 14, 2014	May. 14, 2014	Feb. 14, 2014	Sep. 30, 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 - Narrat

Intangible Assets, Net - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015	Sep. 30, 2014	May. 01, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 7	$ 20	$ 20
Monarch Natural Gas, LLC
Finite-Lived Intangible Assets [Line Items]
Intangibles				$ 10
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Intangible assets	411	$ 411			$ 401
Estimated customer contract life		15 years
Finite-Lived Intangible Assets, Accumulated Amortization	65	$ 65			45
Finite-Lived Intangible Assets, Net	$ 346	$ 346			$ 356

Assessing Impairment of Long-44

Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill -Narrative (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 1997
Goodwill [Line Items]
Goodwill	$ 0	$ 0	$ 1,068
Goodwill Impairment		1,087
Enable Oklahoma
Goodwill [Line Items]
Goodwill				$ 438
Impairments
Goodwill [Line Items]
Goodwill Impairment	1,087	1,087
Transportation and Storage
Goodwill [Line Items]
Goodwill	0	0	579
Goodwill Impairment		579
Transportation and Storage | EGT and MRT | Predecessor
Goodwill [Line Items]
Goodwill					$ 579
Gathering and Processing
Goodwill [Line Items]
Goodwill	0	0	$ 489
Goodwill Impairment		508
Pipelines | Transportation and Storage | Impairments
Goodwill [Line Items]
Impairment	12	12
Pipelines | Gathering and Processing | Impairments
Goodwill [Line Items]
Impairment	$ 6	$ 6

Assessing Impairment of Long-45

Assessing Impairment of Long-lived Assets (including Intangible Assets) and Goodwill -Change in Carrying Amount of Goodwill (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Goodwill [Roll Forward]
Balance as of December 31, 2014	$ 1,068
Acquisition of Monarch	19
Goodwill Impairment	(1,087)
Balance as of September 30, 2015	0
Gathering and Processing
Goodwill [Roll Forward]
Balance as of December 31, 2014	489
Acquisition of Monarch	19
Goodwill Impairment	(508)
Balance as of September 30, 2015	0
Transportation and Storage
Goodwill [Roll Forward]
Balance as of December 31, 2014	579
Acquisition of Monarch	0
Goodwill Impairment	(579)
Balance as of September 30, 2015	$ 0

Investment in Equity Method A46

Investment in Equity Method Affiliates - Narrative (Details) - USD ($) $ in Millions	Jun. 12, 2015	Jul. 25, 2014	Sep. 30, 2015	Sep. 30, 2014	May. 29, 2014	Sep. 30, 2015	Sep. 30, 2014	Jun. 29, 2015	May. 29, 2014	May. 30, 2014	May. 01, 2013
CenterPoint
Distribution to limited partner in third quarter, ended September 30, 2014				$ 1			$ 1
SESH
Limited partner units that may be issued, exercisable as early as May 2014											6,322,457
Fair value of limited partner interests											$ 161
CenterPoint
Limited partner ownership interest						55.40%
SESH
Limited partner ownership interest, exercisable as early as May 2014				24.95%	24.95%
Percentage interest										24.95%
Fair value of limited partner interests			$ 1			$ 1
Ownership percentage			50.00%			50.00%
Percentage of distributions through limited partner interest						50.00%
Distributions from unconsolidated affiliates			$ 10	$ 7		$ 37	13
SESH | Investments in Equity Method Affiliates
Distributions from unconsolidated affiliates		$ 7				$ 37	$ 13
SESH | Put Option
Limited partner ownership interest		49.90%						49.90%
SESH | CenterPoint
Distributed ownership percentage									25.05%
SESH | SESH | Put Option
Limited partner ownership interest, exercisable as early as May 2015	0.10%
Limited partner units that may be issued, exercisable as early as May 2015			25,341			25,341

Investment in Equity Method A47

Investment in Equity Method Affiliates - Schedule of Investments (Details) - USD ($) $ in Millions	Jul. 25, 2014	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balance as of December 31				$ 348
Additional investment in SESH				8	$ 187
Equity in earnings of equity method affiliates		$ 7	$ 5	21	12
Capital contributions from partners				0	464
Balance as of September 30		341		341
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates		7	5	21	12
SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Distributions from equity method affiliate		(10)	(7)	(37)	(13)
Distributions from Equity Method Affiliates:
Distributions from unconsolidated affiliates		(10)	(7)	(37)	(13)
Operating revenues		29	27	86	80
Operating income		18	17	54	50
Net income		14	12	42	34
Other Income (Expense) | SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity in earnings of equity method affiliates		7	5	21	12
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates		7	5	21	12
Investments in Equity Method Affiliates | SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balance as of December 31				348	198
Interest acquisition of SESH				1	161
Distributions from equity method affiliate	$ (7)			(37)	(13)
Additional investment in SESH				0	187
Equity in earnings of equity method affiliates				21	12
Capital contributions from partners				8	2
Balance as of September 30		$ 341	$ 349	341	349
Equity in Earnings of Equity Method Affiliates:
Equity in earnings of equity method affiliates				21	12
Distributions from Equity Method Affiliates:
Distributions from unconsolidated affiliates	$ (7)			(37)	(13)
Investments in Equity Method Affiliates | Special Distribution | SESH
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Distributions from equity method affiliate				0	(198)
Distributions from Equity Method Affiliates:
Distributions from unconsolidated affiliates				$ 0	$ (198)

- Narrative (Details)

- Narrative (Details)		Oct. 09, 2015	Jul. 31, 2015USD ($)time	Sep. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Total debt				$ 3,169,000,000	$ 2,544,000,000
Notes payable — affiliated companies				363,000,000	363,000,000
Short-term debt	[1]			432,000,000	253,000,000
Total long-term debt				2,374,000,000	1,928,000,000
Commercial paper, authorized				1,400,000,000
Other Assets
Debt Instrument [Line Items]
Unamortized debt expense				18,000,000	17,000,000
Term Loan Facility
Debt Instrument [Line Items]
Total debt				450,000,000	0
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity				1,750,000,000
Letters of credit principal advances				0
Letters of credit outstanding amount				$ 2,000,000
Commitment fee percentage				0.20%
Revolving Credit Facility | LIBOR
Debt Instrument [Line Items]
Applicable margin percentage				1.50%
Commercial Paper
Debt Instrument [Line Items]
Total debt				$ 432,000,000	253,000,000
Unsecured term loan facility | Term Loan Facility
Debt Instrument [Line Items]
Duration of term loan facility			3 years
Unsecured term loan facility			$ 450,000,000
Number of times option maybe exercised to extend term of Term Loan Facility | time			2
Extension period			1 year
Minimum prepayment amount of option to prepay without penalty or premium (minimum amount of $1 million)			$ 1,000,000
Multiple amount of prepayment in excess of minimum prepayment			$ 500,000
Unsecured term loan facility | LIBOR | Term Loan Facility
Debt Instrument [Line Items]
Applicable margin percentage				1.375%
Senior Notes
Debt Instrument [Line Items]
Unamortized premium				$ 24,000,000	28,000,000
Senior Notes | 2019 Notes, 2024 Notes, and 2044 Notes | Subsequent Event
Debt Instrument [Line Items]
Additional interest rate percentage		0.25%
Senior Notes | 2019 Notes, 2024 Notes, and 2044 Notes | Subsequent Event | Maximum
Debt Instrument [Line Items]
Additional interest rate percentage		1.00%
Senior Notes | 2.400% Senior Notes
Debt Instrument [Line Items]
Total debt				500,000,000	500,000,000
Senior Notes | 3.900% Senior Notes
Debt Instrument [Line Items]
Total debt				600,000,000	600,000,000
Senior Notes | 5.000% Senior Notes
Debt Instrument [Line Items]
Total debt				550,000,000	550,000,000
Senior Notes | 6.25% Senior Notes
Debt Instrument [Line Items]
Total debt				250,000,000	250,000,000
Unamortized premium				$ 24,000,000	$ 28,000,000
[1]	Short-term debt includes $432 million and $253 million of commercial paper as of September 30, 2015 and December 31, 2014, respectively.

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value Hierarchy (Details) - USD ($) $ in Millions		Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Retained fuel due from shippers		$ 6	$ 4
Over retained fuel due from shippers		5	1
Commodity Contracts | Recurring Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, total fair value		29	40
Liabilities, total fair value		4	4
Assets		(4)	(4)
Liabilities		(4)	(4)
Assets		25	36
Liabilities		0	0
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]
Assets		17	33
Liabilities		3	4
Commodity Contracts | Recurring Measurement | Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		1	2
Liabilities		0	0
Commodity Contracts | Recurring Measurement | Unobservable inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		11	5
Liabilities		1	0
Gas Imbalances | Recurring Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, total fair value	[1],[2]	10	40
Liabilities, total fair value	[2],[3]	12	12
Assets	[1],[2]	0	0
Liabilities	[2],[3]	0	0
Assets	[1],[2]	10	40
Liabilities	[2],[3]	12	12
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]
Assets	[1],[2]	0	0
Liabilities	[2],[3]	0	0
Gas Imbalances | Recurring Measurement | Significant other observable inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	[1],[2]	10	40
Liabilities	[2],[3]	12	12
Gas Imbalances | Recurring Measurement | Unobservable inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	[1],[2]	0	0
Liabilities	[2],[3]	$ 0	$ 0
[1]	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $6 million and $4 million at September 30, 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 September 30, 2015 and December 31, 2014.
[3]	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $5 million and $1 million at September 30, 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 - Carry

Fair Value Measurements - Carrying and Fair Value Amounts (Details) - USD ($) $ in Millions		Sep. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount		$ 3,169	$ 2,544
Carrying value		432	253
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	363
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]	0	0
Carrying Amount | Significant other observable inputs (Level 2) | Term Loan Facility (Level 2)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount		450	0
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		275	279
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	1,649
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		361	362
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]	0	0
Fair Value | Significant other observable inputs (Level 2) | Term Loan Facility (Level 2)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value		450	0
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		275	282
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		$ 1,442	$ 1,592
[1]	Borrowing capacity is reduced by our borrowings outstanding under the commercial paper program. $432 million and $253 million of commercial paper was outstanding as of September 30, 2015 and December 31, 2014, respectively.

Derivative Instruments and He51

Derivative Instruments and Hedging Activities (Details) - Not Designated as Hedging Instrument		9 Months Ended
		Sep. 30, 2015MMBTUMBbls	Sep. 30, 2014MMBTUMBbls	Dec. 31, 2014
Natural gas
Derivative [Line Items]
Percent of contract with durations of one year or less		90.60%		91.20%
Percent of contracts with durations of more than one year and less than two years		9.20%		6.50%
Percent of contracts having a duration of more than two years		0.20%		2.20%
Natural gas | Physical | Purchases
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		2	4
Natural gas | Physical | Sales
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		64	32
Natural gas | Financial fixed futures/swaps | Purchases
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		2	5
Natural gas | Financial fixed futures/swaps | Sales
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		32	35
Natural gas | Financial basis futures/swaps | Purchases
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		3	7
Natural gas | Financial basis futures/swaps | Sales
Derivative [Line Items]
Derivative, gross notional volume (TBtu)		41	54
Condensate
Derivative [Line Items]
Percent of contract with durations of one year or less		88.90%		100.00%
Percent of contracts with durations of more than one year and less than two years		11.10%
Condensate | Financial Futures/swaps | Purchases
Derivative [Line Items]
Derivative, gross notional volume (MMbl) | MBbls		0	0
Condensate | Financial Futures/swaps | Sales
Derivative [Line Items]
Derivative, gross notional volume (MMbl) | MBbls		1	12
Natural gas liquids
Derivative [Line Items]
Percent of contract with durations of one year or less		89.30%
Percent of contracts with durations of more than one year and less than two years		10.70%
Natural gas liquids | Financial Futures/swaps | Purchases
Derivative [Line Items]
Derivative, gross notional volume (MMbl) | MBbls	[1]	0	0
Natural gas liquids | Financial Futures/swaps | Sales
Derivative [Line Items]
Derivative, gross notional volume (MMbl) | MBbls	[1]	1	0
[1]	As of September 30, 2015, 89.3% of the natural gas liquids contracts had durations of one year or less and 10.7% had durations of more than one year and less than two years.

Derivative Instruments and He52

Derivative Instruments and Hedging Activities - Balance Sheet Location (Details) - Not Designated as Hedging Instrument - USD ($)		Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative Instruments		$ 0	$ 0
Assets, Fair Value	[1]	29,000,000	40,000,000
Liabilities, Fair Value	[1]	4,000,000	4,000,000
Natural gas | Financial futures/swaps | Other Current, Assets
Derivatives, Fair Value [Line Items]
Assets, Fair Value		17,000,000	34,000,000
Natural gas | Financial futures/swaps | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Liabilities, Fair Value		3,000,000	4,000,000
Natural gas | Physical purchases/sales | Other Current, Assets
Derivatives, Fair Value [Line Items]
Assets, Fair Value		1,000,000	1,000,000
Natural gas | Physical purchases/sales | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Liabilities, Fair Value		0	0
Condensate | Financial futures/swaps | Other Current, Assets
Derivatives, Fair Value [Line Items]
Assets, Fair Value		2,000,000	5,000,000
Condensate | Financial futures/swaps | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Liabilities, Fair Value		0	0
Natural gas liquids | Financial futures/swaps | Other Current, Assets
Derivatives, Fair Value [Line Items]
Assets, Fair Value		9,000,000	0
Natural gas liquids | Financial futures/swaps | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Liabilities, Fair Value		$ 1,000,000	$ 0
[1]	See Note 9 for a reconciliation of the Partnership’s total derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheet as of September 30, 2015 and December 31, 2014.

Derivative Instruments and He53

Derivative Instruments and Hedging Activities - Amounts Recognized in Income (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	$ 21,000,000	$ 5,000,000	$ 23,000,000	$ 5,000,000
Cash collateral required if ratings are lowered	0		0
Natural gas | Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	10,000,000	3,000,000	13,000,000	4,000,000
Natural gas | Physical purchases/sales
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	(1,000,000)	(1,000,000)	(5,000,000)	(1,000,000)
Condensate | Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	11,000,000	3,000,000	8,000,000	2,000,000
Natural gas liquids | Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	$ 1,000,000	$ 0	$ 7,000,000	$ 0

Supplemental Disclosure of Ca54

Supplemental Disclosure of Cash Flow Information - (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]
Interest, net of capitalized interest	$ 61	$ 53
Income taxes, net of refunds	2	1
Accounts payable related to capital expenditures	66	4
Issuance of common units upon interest acquisition of SESH (Note 7)	$ 1	$ 161

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Related Party Transaction [Line Items]
Partnership's revenues from affiliated companies as a percent of total revenues	6.00%	5.00%	7.00%	5.00%
Notes payable — affiliated companies	$ 363		$ 363		$ 363
Notes payable—affiliated companies	363		$ 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 and OGE Energy
Related Party Transaction [Line Items]
Period notice of termination for reimbursements for all employee costs			90 days
CenterPoint
Related Party Transaction [Line Items]
Notes payable — affiliated companies	363		$ 363
Affiliate interest expense	2	$ 2	6	$ 6
CenterPoint | 2.10% Note Payable
Related Party Transaction [Line Items]
Notes payable—affiliated companies	$ 273		$ 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%		2.10%
CenterPoint | 2.45% Note Payable
Related Party Transaction [Line Items]
Notes payable—affiliated companies	$ 90		$ 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%		2.45%
CenterPoint | Certain Services and Support Functions
Related Party Transaction [Line Items]
Expense reimbursement annual caps			$ 15

Related Party Activity (Details

Related Party Activity (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Related Party Transaction [Line Items]
Revenues from affiliated companies		$ 36	$ 37	$ 121	$ 140
Cost of goods sold from affiliate		6	8	14	16
Charges to the Partnership by affiliates		19	66	50	215
CenterPoint
Related Party Transaction [Line Items]
Cost of goods sold from affiliate		1	0	2	2
CenterPoint | Gas Transportation and Storage
Related Party Transaction [Line Items]
Revenues from affiliated companies		23	22	79	82
CenterPoint | Gas Sales
Related Party Transaction [Line Items]
Revenues from affiliated companies		0	1	7	17
CenterPoint | Seconded Employee Costs
Related Party Transaction [Line Items]
Charges to the Partnership by affiliates		0	32	0	101
CenterPoint | Corporate Services
Related Party Transaction [Line Items]
Charges to the Partnership by affiliates		5	6	12	23
OGE Energy
Related Party Transaction [Line Items]
Cost of goods sold from affiliate		5	8	12	14
OGE Energy | Gas Transportation and Storage
Related Party Transaction [Line Items]
Revenues from affiliated companies	[1]	10	9	28	31
OGE Energy | Gas Sales
Related Party Transaction [Line Items]
Revenues from affiliated companies	[1]	3	5	7	10
OGE Energy | Seconded Employee Costs
Related Party Transaction [Line Items]
Charges to the Partnership by affiliates		12	25	30	78
OGE Energy | Corporate Services
Related Party Transaction [Line Items]
Charges to the Partnership by affiliates		$ 2	$ 3	$ 8	$ 13
[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 Statements 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.

Equity Based Compensation (Deta

Equity Based Compensation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 3	$ 5	$ 9	$ 10
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	1	1	3	1
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	2	3	5	8
Phantom units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 0	$ 1	$ 1	$ 1

Equity Based Compensation - Equ

Equity Based Compensation - Equity Units Activity (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)shares
Minimum
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Percentage of performance target	0.00%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Percentage of performance target	200.00%
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 beginning of period	552,581
Units granted	501,474	[1]
Vested	(1,254)
Forfeited	(222,389)
Number of Units Outstanding at end of period	830,412
Aggregate Intrinsic Value, Units Outstanding at end of period | $	$ 10
Number of Units Fully Vested at end of period	2,799
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 beginning of period	838,068
Units granted	279,677	[1]
Vested	(375,504)
Forfeited	(126,278)
Number of Units Outstanding at end of period	615,963
Aggregate Intrinsic Value, Units Outstanding at end of period | $	$ 8
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 beginning of period	98,718
Units granted	0	[1]
Vested	(90,000)
Forfeited	(2,000)
Number of Units Outstanding at end of period	6,718
Aggregate Intrinsic Value, Units Outstanding at end of period | $	$ 0
Number of Units Fully Vested at end of period	90,500
[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.

Equity Based Compensation - Unr

Equity Based Compensation - Unrecognized Compensation Cost (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)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)	$ 11
Weighted Average to be Recognized (In years)	2 years 3 months 26 days
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 10
Weighted Average to be Recognized (In years)	1 year 11 months 12 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)	29 days
Long Term Incentive Plan | Common Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance | shares	11,056,759

- Schedule of Financial Data fo

- Schedule of Financial Data for Business Segments and Services (Details) $ in Millions		Jun. 12, 2015	May. 01, 2015USD ($)	Sep. 30, 2015USD ($)		Sep. 30, 2014USD ($)		May. 29, 2014	Sep. 30, 2015USD ($)segment		Sep. 30, 2014USD ($)		Dec. 31, 2014USD ($)	May. 30, 2014	Dec. 31, 2013USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment									2
Total revenues				$ 646		$ 803			$ 1,852		$ 2,632
Cost of goods sold, excluding depreciation and amortization				287		439			856		1,550
Operation and maintenance				130		128			391		383
Depreciation and amortization				84		69			233		205
Impairments (Note 6)				1,105		1			1,105		1
Taxes other than income tax				15		14			45		41
Operating (Loss) Income				(975)		152			(778)		452
Total assets				11,201					11,201				$ 11,837
Capital expenditures				198					734	[1]
Capital expenditures						248			654		586
Equity in earnings of equity method affiliates				7		$ 5			21		12
Investment in equity method affiliates				$ 341					$ 341				348
Monarch Natural Gas, LLC
Segment Reporting Information [Line Items]
Acquired gas gathering system			$ 80
SESH
Segment Reporting Information [Line Items]
Limited partner ownership interest, exercisable as early as May 2014						24.95%		24.95%
Percentage interest														24.95%
Ownership percentage				50.00%					50.00%
SESH | SESH | Put Option
Segment Reporting Information [Line Items]
Limited partner ownership interest, exercisable as early as May 2015		0.10%
Gathering and Processing
Segment Reporting Information [Line Items]
Total revenues				$ 456		$ 604			$ 1,279		1,882
Cost of goods sold, excluding depreciation and amortization				235		382			698		1,250
Operation and maintenance				75		76			229		219
Depreciation and amortization				53		41			141		118
Impairments (Note 6)				514		1			514		1
Taxes other than income tax				8		8			23		18
Operating (Loss) Income				(429)		96			(326)		276
Total assets				7,441					7,441				8,356
Capital expenditures				167					657	[1]
Capital expenditures						227					522
Transportation and Storage
Segment Reporting Information [Line Items]
Total revenues				299	[2]	341	[2]		875	[3]	1,219	[3]
Cost of goods sold, excluding depreciation and amortization				161	[2]	198	[2]		459	[3]	768	[3]
Operation and maintenance				55	[2]	53	[2]		163	[3]	165	[3]
Depreciation and amortization				31	[2]	28	[2]		92	[3]	87	[3]
Impairments (Note 6)				591	[2]	0	[2]		591	[3]	0	[3]
Taxes other than income tax				7	[2]	6	[2]		22	[3]	23	[3]
Operating (Loss) Income				(546)	[2]	56	[2]		(452)	[3]	176	[3]
Total assets	[2],[3]			4,857					4,857				5,493
Capital expenditures				31	[2]				77	[1],[3]
Capital expenditures						25	[2]				69	[3]
Eliminations
Segment Reporting Information [Line Items]
Total revenues				(109)		(142)			(302)		(469)
Cost of goods sold, excluding depreciation and amortization				(109)		(141)			(301)		(468)
Operation and maintenance				0		(1)			(1)		(1)
Depreciation and amortization				0		0			0		0
Impairments (Note 6)				0		0			0		0
Taxes other than income tax				0		0			0		0
Operating (Loss) Income				0		0			0		0
Total assets				(1,097)					(1,097)				(2,012)
Capital expenditures				0					0	[1]
Capital expenditures						(4)					(5)
Investments in Equity Method Affiliates | SESH
Segment Reporting Information [Line Items]
Equity in earnings of equity method affiliates									21		12
Investment in equity method affiliates				341		349			341		349		$ 348		$ 198
Other Income (Expense) | SESH
Segment Reporting Information [Line Items]
Equity in earnings of equity method affiliates				$ 7		$ 5			$ 21		$ 12
[1]	As discussed in Note 1, the Partnership acquired a gas gathering system for $80 million from Monarch Natural Gas, LLC on May 1, 2015.
[2]	Transportation and Storage recorded equity income of $7 million and $5 million for the three months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015, the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH.
[3]	Transportation and Storage recorded equity income of $21 million and $12 million for the nine months ended September 30, 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 $341 million and $348 million as of September 30, 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. On June 30, 2015, CenterPoint Energy contributed its remaining 0.1% interest in SESH to the Partnership. As of September 30, 2015, the Partnership owns 50% interest in SESH. See Note 7 for further discussion regarding SESH.