Resources Connection 10-Q 7 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014
Entity Information	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Trading Symbol	'RGP	'
Entity Registrant Name	'Regency Energy Partners LP	'
Entity Central Index Key	'0001338613	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	397,703,627

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$50	$19
Trade accounts receivable, net	449	292
Related party receivables	19	28
Inventories	60	42
Other current assets	14	19
Total current assets	592	400
Property, plant and equipment	8,256	5,050
Less accumulated depreciation and depletion	-840	-632
Property, plant and equipment, net	7,416	4,418
Investment in unconsolidated affiliates	2,378	2,097
Other, net of accumulated amortization of debt issuance costs of $28 and $24	87	57
Intangible assets, net of accumulated amortization of $150 and $107	3,500	682
Goodwill	1,486	1,128
TOTAL ASSETS	15,459	8,782
Current Liabilities:	'	'
Drafts payable	0	26
Trade accounts payable	353	291
Related party payables	215	69
Accrued interest	65	38
Other current liabilities	97	51
Total current liabilities	730	475
Long-term derivative liabilities	29	19
Other long-term liabilities	59	30
Long-term debt, net	5,490	3,310
Commitments and contingencies	'	'
Series A Preferred Units, redemption amounts of $38 and $38	32	32
Partners’ capital and noncontrolling interest:	'	'
Common units	8,079	3,886
Class F units	150	146
General partner interest	783	782
Total partners’ capital	9,012	4,814
Noncontrolling interest	107	102
Total partners’ capital and noncontrolling interest	9,119	4,916
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$15,459	$8,782

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets Balance Sheet (Paranthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Paranthetical [Abstract]	'	'
Other, accumulated amortization of debt issuance costs	$28	$24
Intangible assets, net of accumulated amortization	150	107
Series A preferred units, redemption amount	$38	$38

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
REVENUES	'	'	'	'
Gas sales, including related party amounts of $22, $26, $35 and $34	$475	$220	$810	$387
NGL sales, including related party amounts of $57, $11, $107 and $12	422	245	753	480
Gathering, transportation and other fees, including related party amounts of $7, $6, $13 and $14	227	131	399	258
Net realized and unrealized (loss) gain from derivatives	-5	14	-18	11
Other	59	29	97	43
Total revenues	1,178	639	2,041	1,179
OPERATING COSTS AND EXPENSES	'	'	'	'
Cost of sales, including related party amounts of $16, $23, $26 and $27	828	445	1,466	832
Operation and maintenance	93	73	171	142
General and administrative	54	18	87	51
Loss (gain) on asset sales, net	0	1	-2	2
Depreciation, depletion and amortization	168	68	262	133
Total operating costs and expenses	1,143	605	1,984	1,160
OPERATING INCOME	35	34	57	19
Income from unconsolidated affiliates	47	31	90	66
Interest expense, net	-78	-41	-134	-78
Loss on debt refinancing, net	0	-7	0	-7
Other income and deductions, net	-7	-7	-5	-21
(LOSS) INCOME BEFORE INCOME TAXES	-3	10	8	-21
Income tax expense (benefit)	1	-1	0	-3
NET (LOSS) INCOME	-4	11	8	-18
Net income attributable to noncontrolling interest	-4	-1	-7	-1
NET (LOSS) INCOME ATTRIBUTABLE TO REGENCY ENERGY PARTNERS LP	-8	10	1	-19
Amounts attributable to Series A Preferred Units	1	2	2	4
General partner’s interest, including IDRs	7	3	12	5
Beneficial conversion feature for Class F units	2	1	4	1
Pre-acquisition loss from SUGS allocated to predecessor equity	0	-9	0	-33
Limited partners’ interest in net (loss) income	-18	13	-17	4
Basic and diluted net (loss) income per common unit:	'	'	'	'
Weighted average number of common units outstanding	361,071,005	193,065,183	293,931,615	182,070,077
Basic (loss) income per common unit	($0.05)	$0.07	($0.06)	$0.02
Diluted (loss) income per common unit	($0.05)	$0.07	($0.06)	$0.02
Distributions per common unit	$0.49	$0.47	$0.97	$0.93
Amount allocated to Class F units due to beneficial conversion feature	$2	$1	$4	$1
Total number of Class F units outstanding	6,274,483	6,274,483	6,274,483	6,274,483
Income per Class F unit due to beneficial conversion feature	$0.27	$0.18	$0.54	$0.18

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Operations Statements of Operations (Paranthetical) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Paranthetical [Abstract]	'	'	'	'
Gas sales, related party amounts	$22	$26	$35	$34
NGL sales, related party amounts	57	11	107	12
Gathering, transportation and other fees, related party amounts	7	6	13	14
Cost of sales, related party amounts	$16	$23	$26	$27

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net (loss) income	($4)	$11	$8	($18)
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	-4	11	8	-18
Comprehensive income attributable to noncontrolling interest	4	1	7	1
Comprehensive (loss) income attributable to Regency Energy Partners LP	($8)	$10	$1	($19)

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
OPERATING ACTIVITIES:	'	'
Net income (loss)	$8	($18)
Reconciliation of net income (loss) to net cash flows provided by operating activities:	'	'
Depreciation, depletion and amortization, including debt issuance cost amortization and bond premium write-off and amortization	264	137
Income from unconsolidated affiliates	-90	-66
Derivative valuation changes	13	17
Loss (gain) on asset sales, net	-2	2
Unit-based compensation expenses	5	3
Cash flow changes in current assets and liabilities:	'	'
Trade accounts receivable and related party receivables	-17	-41
Other current assets and other current liabilities	26	-51
Trade accounts payable and related party payables	-36	10
Distributions of earnings received from unconsolidated affiliates	96	71
Cash flow changes in other assets and liabilities	10	131
Net cash flows provided by operating activities	277	195
INVESTING ACTIVITIES:	'	'
Capital expenditures	-401	-472
Capital contributions to unconsolidated affiliates	-83	-72
Distributions in excess of earnings of unconsolidated affiliates	20	37
Acquisitions, net of cash received	-212	-463
Proceeds from asset sales	6	12
Net cash flows used in investing activities	-670	-958
FINANCING ACTIVITIES:	'	'
(Repayments) borrowings under revolving credit facility, net	-275	343
Proceeds from issuances of senior notes	884	600
Redemptions of senior notes	-313	-163
Debt issuance costs	-22	-17
Drafts payable	-25	7
Partner distributions and distributions on unvested unit awards	-286	-179
Common unit offering, net of issuance costs	400	128
Common units issued under equity distribution program, net of costs	65	0
Distributions to Series A Preferred Units	-2	-4
Noncontrolling interest (distributions) contributions	-2	12
Net cash flows provided by financing activities	424	727
Net change in cash and cash equivalents	31	-36
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	50	17
Supplemental cash flow information:	'	'
Accrued capital expenditures	48	133
Accrued capital contribution to unconsolidated affiliates	175	22
Issuance of Class F and common units in connection with SUGS Acquisition	0	1,223
Interest paid, net of amounts capitalized	134	0
Issuance of common units in connection with PVR and Hoover acquisitions	4,015	0
Long-term debt assumed in PVR Acquisition	$1,887	$0

Condensed_Consolidated_Stateme4

Condensed Consolidated Statement of Partners' Capital and Noncontrolling Interest (USD $)	Total	Common Units [Member]	Class F Units [Member]	General Partner Interest	Noncontrolling Interest
In Millions
Balance at Dec. 31, 2013	$4,916	$3,886	$146	$782	$102
Issuance of common units under equity distribution program, net of costs	65	65	0	0	0
Issuance of common units to ETE Common Holdings	400	400	0	0	0
Issuance of common units in connection with Hoover Acquisition	109	109	0	0	0
Issuance of common units in connection with PVR Acquisition	3,906	3,906	0	0	0
Unit-based compensation expenses	5	5	0	0	0
Partner distributions and distributions on unvested unit awards	-286	-275	0	-11	0
Noncontrolling interest distributions, net	-2	0	0	0	-2
Net income (loss)	8	-15	4	12	7
Distributions to Series A Preferred Units	-2	-2	0	0	0
Balance at Jun. 30, 2014	$9,119	$8,079	$150	$783	$107

Organization_And_Summary_Of_Si

Organization And Summary Of Significant Accounting Policies (Notes)	6 Months Ended
	Jun. 30, 2014
Organization And Summary Of Significant Accounting Policies	'
Organization And Summary Of Significant Accounting Policies	'
	Organization and Summary of Significant Accounting Policies
	Organization. The unaudited condensed consolidated financial statements presented herein contain the results of Regency Energy Partners LP and its subsidiaries (the “Partnership”), a Delaware limited partnership. The Partnership and its subsidiaries are engaged in the business of gathering and processing, compression, treating and transportation of natural gas; the transportation, fractionation and storage of NGLs; the gathering, transportation and terminaling of oil (crude and/or condensate, a lighter oil) received from producers; and the management of coal and natural resource properties in the United States. Regency GP LP is the Partnership’s general partner and Regency GP LLC (collectively the “General Partner”) is the managing general partner of the Partnership and the general partner of Regency GP LP.
	SUGS Acquisition. On April 30, 2013, the Partnership and Regency Western acquired SUGS from Southern Union, a wholly-owned subsidiary of Holdco, for $1.5 billion (the “SUGS Acquisition”).
	The Partnership accounted for the acquisition in a manner similar to the pooling of interests method of accounting as it was a transaction between commonly controlled entities. The Partnership retrospectively adjusted its March 31, 2013 financial statements to include the operations of SUGS for periods prior to April 30, 2013. The SUGS Acquisition did not impact historical earnings per unit as pre-acquisition earnings were allocated to predecessor equity.
	The following table presents the revenues and net income for the previously separate entities and the combined amounts presented herein:
		Three Months Ended June 30, 2013			Six Months Ended June 30, 2013 (1)
	Revenues:
	Partnership	$	562		$	911
	SUGS	77			268
	Combined	$	639		$	1,179
	Net income (loss):
	Partnership	$	20		$	15
	SUGS	(9		)	(33		)
	Combined	$	11		$	(18	)
	(1) The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include one month and four months of activity for the three months and six months ended June 30, 2013, respectively.
	Basis of Presentation. The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2013. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All inter-company items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
	Use of Estimates. The unaudited condensed consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
	Equity Method Investments. Even though there is a presumption of a controlling financial interest in Aqua - PVR (because of our 51% ownership), our partner in this joint venture has substantive participating rights and management authority that preclude us from controlling the joint venture. Therefore, it is accounted for as an equity method investment.
	Coal Royalties Revenues and Deferred Income. The Partnership recognizes coal royalties revenues on the basis of tons of coal sold by its lessees and the corresponding revenues from those sales. The Partnership does not have access to actual production and revenues information until 30 days following the month of production. Therefore, financial results include estimated revenues and accounts receivable for the month of production. The Partnership records any differences between the actual amounts ultimately received or paid and the original estimates in the period they become finalized. Most lessees must make minimum monthly or annual payments that are generally recoverable over certain time periods. These minimum payments are recorded as deferred income. If the lessee recovers a minimum payment through production, the deferred income attributable to the minimum payment is recognized as coal royalties revenues. If a lessee fails to meet its minimum production for certain pre-determined time periods, the deferred income attributable to the minimum payment is recognized as minimum rental revenues, which is a component of other revenues on our consolidated statements of operations. Other liabilities on the balance sheet also include deferred unearned income from a coal services facility lease, which is recognized as other income as it is earned.
	New Accounting Pronouncement. In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. The Partnership is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies.

Partners_Capital_and_Distribut

Partners' Capital and Distributions (Notes)	6 Months Ended
	Jun. 30, 2014
Partners’ Capital and Distributions [Abstract]	'
Partners' Capital Notes Disclosure [Text Block]	'
	Partners’ Capital and Distributions
	Beneficial Conversion Feature. The beneficial conversion feature, incurred as a result of the issuance of Class F units, is reflected in income per unit using the effective yield method over the period the Class F units are outstanding, as indicated on the statement of operations in the line item entitled “beneficial conversion feature for Class F units.” The Class F units will convert to common units on a one-for-one basis on May 8, 2015.
	Equity Distribution Agreement. In June 2012, the Partnership entered into an equity distribution agreement with Citi under which the Partnership may offer and sell common units having an aggregate offering price of up to $200 million, from time to time through Citi, as sales agent for the Partnership. Sales of these units made from time to time under the equity distribution agreement were made by means of ordinary brokers’ transactions on the New York Stock Exchange at market prices, in block transactions, or as otherwise agreed upon by the Partnership and Citi. The Partnership used the net proceeds from the sale of these common units for general partnership purposes. During the six months ended June 30, 2014, the Partnership received net proceeds of $34 million from common units sold pursuant to this equity distribution agreement and no amounts remained available to be issued under this agreement and it is no longer effective.
	In May 2014, the Partnership entered into an equity distribution agreement with Barclays under which the Partnership may offer and sell common units having an aggregate offering price of up to $400 million, from time to time through Barclays, as sales agent for the Partnership. Sales of these units made from time to time under the equity distribution agreement will be made by means of ordinary brokers’ transactions on the New York Stock Exchange at market prices, in block transactions, or as otherwise agreed upon by the Partnership and Barclays. The Partnership may also sell common units to Barclays as principal for its own account at a price agreed upon at the time of sale. Any sale of common units to Barclays as principal would be pursuant to the terms of a separate agreement between the Partnership and Barclays. The Partnership intends to use the net proceeds from the sale of these units for general partnership purposes. During the six months ended June 30, 2014, the Partnership received net proceeds of $31 million from common units sold pursuant to this equity distribution agreement.
	Common Units Sold. In June 2014, the Partnership sold 14.4 million common units to ETE Common Holdings for proceeds of $400 million. Proceeds from the issuance were used to pay down borrowings on the Partnership’s revolving credit facility, to redeem certain senior notes of the Partnership and for general partnership purposes. In July 2014, the Partnership sold 16.5 million common units to ETE Common Holdings for proceeds of $400 million, and issued 8.2 million common units to Eagle Rock in connection with the Eagle Rock Midstream Acquisition.
	Units Activity. The change in common and Class F units during the six months ended June 30, 2014 was as follows:
		Common		Class F
	Balance - December 31, 2013	210,850,232		6,274,483
	Issuance of common units under LTIP, net of forfeitures and tax withholding	24,808		—
	Issuance of common units under the equity distribution agreements	2,374,397		—
	Issuance of common units in connection with Hoover Acquisition	4,040,471		—
	Issuance of common units in connection with PVR Acquisition	140,388,382		—
	Issuance of common units to ETE Common Holdings	14,398,848		—
	Balance - June 30, 2014	372,077,138		6,274,483
	Quarterly Distributions of Available Cash. Following are distributions declared by the Partnership subsequent to December 31, 2013:
	Quarter Ended		Record Date	Payment Date	Cash Distributions
					(per common unit)
	December 31, 2013		February 7, 2014	February 14, 2014	$0.48
	March 31, 2014		May 8, 2014	May 15, 2014	$0.48
	June 30, 2014		August 7, 2014	August 14, 2014	$0.49

Loss_Income_Per_Limited_Partne

(Loss) Income Per Limited Partner Unit (Notes)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Income (Loss) Per Limited Partner Unit	'
	(Loss) Income per Common Unit
	The following tables provide a reconciliation of the numerator and denominator of the basic and diluted earnings per common unit computations for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30,
		2014									2013
		Loss				Units		Per-Unit			Income		Units	Per-Unit
		(Numerator)				(Denominator)		Amount			(Numerator)		(Denominator)	Amount
	Basic (loss) income per unit
	Amount allocated to common units	$	(18	)		361,071,005		$	(0.05	)	$	13	193,065,183	$	0.07
	Effect of Dilutive Securities:
	Common unit options	—				—					—		24,365
	Phantom units	—				—					—		331,462
	Diluted (loss) income per unit	$	(18	)		361,071,005		$	(0.05	)	$	13	193,421,010	$	0.07
		Six Months Ended June 30,
		2014									2013
		Loss				Units		Per-Unit			Income		Units	Per-Unit
		(Numerator)				(Denominator)		Amount			(Numerator)		(Denominator)	Amount
	Basic (loss) income per unit
	Amount allocated to common units	$	(17	)		293,931,615		$	(0.06	)	$	4	182,070,077	$	0.02
	Effect of Dilutive Securities:
	Common unit options	—				—					—		19,035
	Phantom units	—				—					—		303,218
	Diluted (loss) income per unit	$	(17	)		293,931,615		$	(0.06	)	$	4	182,392,330	$	0.02
	The following data show securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit because to do so would have been antidilutive for the periods presented:
		Three Months Ended June 30,					Six Months Ended June 30,
		2014			2013		2014			2013
	Common unit options	25,165			—		24,188			—
	Phantom units	580,935			—		505,235			—
	Series A Preferred Units	2,057,662			4,672,835		2,055,949			4,672,835

Acquisitions_Notes

Acquisitions (Notes)	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	'
	Acquisitions
	2014
	Eagle Rock Midstream Acquisition. On July 1, 2014, the Partnership acquired Eagle Rock’s midstream business (the “Eagle Rock Midstream Acquisition”) for $1.3 billion, including the assumption of $499 million of Eagle Rock’s 8.375% Senior Notes due 2019. The remainder of the purchase price was funded by $400 million in common units sold to ETE Common Holdings, 8.2 million common units issued to Eagle Rock, and borrowings under the revolving credit facility. The Partnership will account for the Eagle Rock Midstream Acquisition using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. The evaluation of the assigned fair values is ongoing as the transaction was recently completed and therefore the Partnership was not able to complete the preliminary allocation of the purchase price to the acquired assets and liabilities prior to the issuance of these financial statements. This acquisition is expected to complement the Partnership’s core gathering and processing business and, when combined with the PVR Acquisition, is expected to further diversify the Partnership’s basin exposure in the Texas Panhandle, east Texas and south Texas.
	PVR Acquisition. On March 21, 2014, the Partnership acquired PVR for a total purchase price of $5.7 billion (based on the Partnership’s closing price of $27.82 per unit on March 21, 2014), including $1.8 billion principal amount of assumed debt (“PVR Acquisition”). PVR unitholders received (on a per unit basis) 1.02 Partnership common units and a one-time cash payment of $36.1 million, which was funded through borrowings under the Partnership’s revolving credit facility. The PVR Acquisition enhances the Partnership’s geographic diversity with a strategic presence in the Marcellus and Utica shales in the Appalachian Basin and the Granite Wash in the Mid-Continent region. The Partnership accounted for the acquisition of PVR using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. Revenues attributable to PVR’s operations included in the statement of operations for the three and six months ended June 30, 2014 were $314 million and $351 million, respectively. Net income attributable to PVR’s operations included in the statement of operations for the three and six months ended June 30, 2014 were $33 million and $35 million, respectively.
	Management is in the process of finalizing the evaluation of the assigned fair values to the assets acquired and liabilities assumed. The total purchase was allocated as follows:
	Assets	At March 21, 2014
	Current assets	$	140
	Gathering and transmission systems	1,396
	Compression equipment	342
	Gas plants and buildings	110
	Natural resources	454
	Other property, plant and equipment	229
	Construction in process	172
	Investment in unconsolidated subsidiaries	62
	Intangible assets	2,717
	Goodwill (1)	353
	Other long-term assets	18
	Total Assets Acquired	$	5,993
	Liabilities
	Current liabilities	$	161
	Long-term debt	1,788
	Premium related to senior notes	99
	Long-term liabilities	42
	Total Liabilities Assumed	$	2,090
	Net Assets Acquired	$	3,903
	(1) Goodwill is reported in the Gathering and Processing segment.
	The fair values of the assets acquired and liabilities assumed were determined using various valuation techniques, including the income and market approaches.
	Assets. Cash and cash equivalents, accounts receivable, net, other current assets, and construction in process, were valued using a cost basis as this basis approximates fair value due to the current nature of these items. Real property, including gathering and transmission systems, compression equipment, gas plants and buildings, and other property, plant and equipment, were valued based on a combination of the income, market and cost approaches, depending on the type of asset. Coal and timber reserves were valued using the income approach for active coal and timber reserves. The investments in unconsolidated subsidiaries were valued using the income approach. Intangible assets, other than goodwill, are customer contract related intangibles, which have an average useful life of 30 years, and have been valued using the income approach. The goodwill is the excess of the consideration transferred over the net assets recognized and represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized.
	Liabilities. The Partnership assumed accounts payable, accrued liabilities, deferred income, and other long-term liabilities as part of the PVR Acquisition. The Partnership determined that the historical cost basis of these liabilities approximated fair value as they comprise normal operating liabilities. The Partnership assumed long-term debt as part of the acquisition, consisting of amounts outstanding under PVR’s revolving credit facility and PVR’s outstanding senior notes. The amount related to the revolving credit facility was valued at historical book value while the senior notes were valued using quoted market prices, which are considered Level 1 inputs.
	Change in Control. The PVR Acquisition constituted a change of control for certain PVR employment agreements. Pursuant to the terms of those agreements, certain payments and benefits, including severance payments, were triggered by the PVR Acquisition. From the date of the PVR Acquisition, the Partnership has recorded $10 million of severance payments due to the change in control. Additionally, the Partnership has recorded $2 million in retention bonuses that are payable to various retained PVR employees upon the expiration of their retention period.
	Hoover Energy Acquisition. On February 3, 2014, the Partnership acquired certain subsidiaries of Hoover for a total purchase price of $293.2 million, consisting of (i) 4,040,471 common units issued to Hoover and (ii) $183.6 million in cash, and (iii) $2 million in asset retirement obligations assumed (the “Hoover Acquisition”). The Hoover Acquisition increases the Partnership’s fee-based revenue, expanding its existing footprint in the southern portion of the Delaware Basin in west Texas, and its services to producers into crude and water gathering. A portion of the consideration is being held in escrow as security for certain indemnification claims. The Partnership financed the cash portion of the purchase price through borrowings under its revolving credit facility. The Partnership accounted for the Hoover Acquisition using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. Revenues attributable to Hoover’s operations included in the statement of operations for the three and six months ended June 30, 2014 were $10 million and $15 million, respectively. Net income attributable to Hoover’s operations included in the statement of operations for the three and six months ended June 30, 2014 were $2 million and $4 million, respectively.
	Management completed the evaluation of the assigned fair values to the assets acquired and liabilities assumed. The total purchase price was allocated as follows:
	Assets	At February 3, 2014
	Accounts receivable, net	$	5
	Gathering and transmission systems	72
	Compression equipment	15
	Other property, plant, and equipment	22
	Construction in process	6
	Intangible assets	148
	Goodwill (1)	30
	Total Assets Acquired	$	298
	Liabilities
	Accounts payable and accrued liabilities	$	5
	Asset retirement obligation	2
	Total Liabilities Assumed	$	7
	Net Assets Acquired	$	291
	(1) Goodwill is reported in the Gathering and Processing segment.
	The fair values of the assets acquired and liabilities assumed were determined using various valuation techniques, including the income and market approaches.
	Assets. Accounts receivable, net, other current assets, and construction in process were valued using a cost basis as this basis approximates fair value due to the current nature of these items. Real property, including gathering and transmission systems, compression equipment, and other property, plant and equipment, were valued based on a combination of the income, market and cost approaches, depending on the type of asset. Intangible assets, other than goodwill, are customer contract related intangibles, which have an average useful life of 30 years, and have been valued using the income approach. The goodwill is the excess of the consideration transferred over the net assets recognized and represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized.
	Liabilities. The Partnership assumed accounts payable, accrued liabilities, and an asset retirement obligation as part of the Hoover Acquisition. The Partnership determined that the historical cost basis of the accounts payable and the accrued liabilities approximated fair value as they comprise normal operating liabilities. The asset retirement obligation was valued based on estimates prepared by an independent environmental consulting firm.
	Pro Forma Results of Operations
	The following unaudited pro forma consolidated results of operations for the three and six months ended June 30, 2014 and 2013 are presented as if the PVR and Hoover acquisitions had been completed on January 1, 2013. The pro forma information includes adjustments to reflect incremental expenses associated with the fair value adjustments recorded as a result of applying the acquisition method of accounting and incremental interest expense related to the financing of a portion of the purchase price. This pro forma information is not necessarily indicative of the results that would have occurred had the acquisitions occurred on January 1, 2013, nor is it indicative of future results of operations.
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Revenues	$	1,178		$	923		$	2,323		$	1,731
	Net loss attributable to the Partnership	(18		)	(20		)	(53		)	(78		)
	Basic net loss per Limited Partner unit	$	(0.05	)	$	(0.07	)	$	(0.16	)	$	(0.27	)
	Diluted net loss per Limited Partner unit	$	(0.05	)	$	(0.07	)	$	(0.16	)	$	(0.27	)

Investment_In_Unconsolidated_A

Investment In Unconsolidated Affiliates (Notes)	6 Months Ended
	Jun. 30, 2014
Investment In Unconsolidated Subsidiaries [Abstract]	'
Investment In Unconsolidated Affiliates	'
	Investment in Unconsolidated Affiliates
	As of June 30, 2014, the Partnership has a 49.99% general partner interest in HPC, a 50% membership interest in MEP, a 30% membership interest in Lone Star, a 33.33% membership interest in Ranch JV, a 51% membership interest in Aqua - PVR, and a 50% interest in Coal Handling. The Partnership’s interest in the Aqua - PVR and Coal Handling joint ventures was acquired in the PVR Acquisition. In March 2014, the Partnership entered into a settlement agreement, whereby the Partnership’s 50% interest in Grey Ranch was assigned to SandRidge Midstream, Inc., resulting in a cash settlement of $4 million and a loss of $1 million recorded to income from unconsolidated affiliates. In June 2014, the Partnership agreed to guarantee the prompt payment by Regency Midcontinent Express LLC of its proportionate $175 million capital contributions to MEP. The Partnership’s obligation is not expected to exceed $176 million.
	The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of June 30, 2014 and December 31, 2013 is as follows:
		June 30, 2014			December 31, 2013
	HPC	$	434		$	442
	MEP	709			548
	Lone Star	1,135			1,070
	Ranch JV	39			36
	Aqua - PVR	50			—
	Coal Handling	11			—
	Grey Ranch	—			1
	Total	$	2,378		$	2,097
	The following tables summarize the Partnership’s investment activities in each of the unconsolidated affiliates for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	44		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(11		)	(19		)	(32		)	(1		)	—			—
	Share of earnings of unconsolidated affiliates’ net income (loss)	8			12			27			3			(1		)	—
	Amortization of excess fair value of investment	(2		)	—			—			—			—			—
		Three Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	22		$	—
	Distributions from unconsolidated affiliates	(14		)	(18		)	(23		)	—
	Share of earnings of unconsolidated affiliates’ net income	9			10			13			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Six Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	71		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(21		)	(37		)	(57		)	(1		)	—			—
	Share of earnings of unconsolidated affiliates’ net income (loss)	16			22			51			5			(1		)	—
	Amortization of excess fair value of investment	(3		)	—			—			—			—			—
		Six Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	49		$	1
	Distributions from unconsolidated affiliates	(30		)	(38		)	(40		)	—
	Share of earnings of unconsolidated affiliates’ net income	19			20			30			—
	Amortization of excess fair value of investment	(3		)	—			—			—
	The following tables present selected income statement data for each of the unconsolidated affiliates, on a 100% basis, for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	37		$	66		$	880		$	11		$	1		$	3
	Operating income (loss)	20			35			90			7			(3		)	1
	Net income (loss)	16			23			89			8			(2		)	1
		Three Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	63		$	425		$	3
	Operating income	19			33			45			1
	Net income	18			21			44			1
		Six Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	74		$	132		$	1,693		$	20		$	1		$	3
	Operating income (loss)	38			69			174			14			(3		)	1
	Net income (loss)	31			44			172			14			(2		)	1
		Six Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	78		$	128		$	783		$	6
	Operating income	39			67			101			1
	Net income	38			42			99			1

Derivative_Instruments_Notes

Derivative Instruments (Notes)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	Policies. The Partnership established comprehensive risk management policies and procedures to monitor and manage the market risks associated with commodity prices, counterparty credit and interest rates. The General Partner is responsible for delegation of transaction authority levels, and the Audit and Risk Committee of the General Partner is responsible for overseeing the management of these risks, including monitoring exposure limits. The Audit and Risk Committee receives regular briefings on exposures and overall risk management in the context of market activities.
	Commodity Price Risk. The Partnership is a net seller of NGLs, condensate and natural gas as a result of its gathering and processing operations. The prices of these commodities are impacted by changes in supply and demand as well as market forces. Both the Partnership’s profitability and cash flow are affected by the inherent volatility of these commodities which could adversely affect its ability to make distributions to its unitholders. The Partnership manages this commodity price exposure through an integrated strategy that includes management of its contract portfolio, matching sales prices of commodities with purchases, optimization of its portfolio by monitoring basis and other price differentials in operating areas, and the use of derivative contracts. In some cases, the Partnership may not be able to match pricing terms or cover its risk to price exposure with financial hedges, and it may be exposed to commodity price risk. Speculative positions with derivative contracts are prohibited under the Partnership’s policies.
	Interest Rate Risk. The Partnership is exposed to variable interest rate risk as a result of borrowings under its revolving credit facility. As of June 30, 2014, the Partnership had $850 million of outstanding borrowings exposed to variable interest rate risk.
	Credit Risk. The Partnership’s resale of NGLs, condensate and natural gas exposes it to credit risk, as the margin on any sale is generally a very small percentage of the total sales price. Therefore, a credit loss can be very large relative to overall profitability on these transactions. The Partnership attempts to ensure that it issues credit only to credit-worthy counterparties and that in appropriate circumstances any such extension of credit is backed by adequate collateral, such as a letter of credit or parental guarantee from a parent company with potentially better credit.
	The Partnership is exposed to credit risk from its derivative contract counterparties. The Partnership does not require collateral from these counterparties. The Partnership deals primarily with financial institutions when entering into financial derivatives, and utilizes master netting agreements that allow for netting of swap contract receivables and payables in the event of default by either party. If the Partnership’s counterparties failed to perform under existing swap contracts, the Partnership’s maximum loss as of June 30, 2014 would be $2 million, which would be reduced by $1 million, due to the netting features. The Partnership has elected to present assets and liabilities under master netting agreements gross on the condensed consolidated balance sheets.
	Embedded Derivatives. The Series A Preferred Units contain embedded derivatives which are required to be bifurcated and accounted for separately, such as the holders’ conversion option and the Partnership’s call option. These embedded derivatives are accounted for using mark-to-market accounting. The Partnership does not expect the embedded derivatives to affect its cash flows.
	The Partnership’s derivative assets and liabilities, including credit risk adjustments, as of June 30, 2014 and December 31, 2013 are detailed below:
		Assets						Liabilities
		June 30, 2014			December 31, 2013			June 30, 2014		December 31, 2013
	Derivatives not designated as cash flow hedges
	Current amounts
	Commodity contracts	$	2		$	3		$	11	$	9
	Long-term amounts
	Commodity contracts	—			1			—		—
	Embedded derivatives in Series A Preferred Units	—			—			29		19
	Total derivatives	$	2		$	4		$	40	$	28
	The Partnership’s statements of operations for the three and six months ended June 30, 2014 and 2013 were impacted by derivative instruments activities as follows:
				Three Months Ended June 30,
				2014			2013
	Derivatives not designated in a hedging relationship		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(5	)	$	14
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(9		)	(8		)
				$	(14	)	$	6
				Six Months Ended June 30,
				2014			2013
	Derivatives not designated in a hedging relationship		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(18	)	$	11
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(10		)	(22		)
				$	(28	)	$	(11	)

LongTerm_Debt_Notes

Long-Term Debt (Notes)	6 Months Ended
	Jun. 30, 2014
Long-Term Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-term Debt
	Obligations in the form of senior notes and borrowings under the revolving credit facility are as follows:
		June 30, 2014			December 31, 2013
	Senior notes	$	4,572		$	2,800
	Revolving loans	850			510
	Unamortized premium and discounts	68			—
	Long-term debt	$	5,490		$	3,310
	Availability under revolving credit facility:
	Total credit facility limit	$	1,500		$	1,200
	Revolving loans	(850		)	(510		)
	Letters of credit	(28		)	(14		)
	Total available	$	622		$	676
	Long-term debt maturities as of June 30, 2014 for each of the next five years are as follows:
	Years Ending December 31,		Amount
	2014 (remainder)		$	—
	2015		—
	2016		—
	2017		—
	2018		600
	Thereafter		4,822
	Total *		$	5,422
	*	Excludes a $82 million unamortized premium on the PVR senior notes assumed by the Partnership and a $14 million unamortized discount on the 2022 Notes.
	Revolving Credit Facility
	In February 2014, RGS entered into the First Amendment to the Sixth Amended and Restated Credit Agreement (as amended, the “Credit Agreement”) to, among other things, expressly permit the pending PVR and Eagle Rock Midstream acquisitions, and to increase the commitment to $1.5 billion and increase the uncommitted incremental facility to $500 million. The amendment specifically allows the Partnership to assume the series of PVR senior notes that mature prior to the Credit Agreement.
	The weighted average interest rate on the total amounts outstanding under the Partnership’s revolving credit facility was 2.66% as of June 30, 2014.
	Senior Notes
	In February 2014, the Partnership and Finance Corp. issued $900 million of senior notes that mature on March 1, 2022 (the “2022 Notes”). The 2022 Notes bear interest at 5.875% with interest payable semi-annually in arrears on September 1 and March 1. At any time prior to December 1, 2021, the Partnership may redeem some or all of the notes at 100% of the principal amount thereof, plus a “make-whole” redemption price and accrued and unpaid interest, if any, to the redemption date. On or after December 1, 2021, the Partnership may redeem some or all of the notes at a redemption price equal to 100% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date. If the Partnership undergoes certain change of control transactions, the Partnership may be required to offer to purchase the notes from holders. The 2022 Notes are guaranteed by the Partnership’s existing consolidated subsidiaries except Finance Corp and ELG. The 2022 Notes rank equally in right of payment with all of the Partnership’s existing and future senior unsecured debt, including the Partnership’s other outstanding Senior Notes, and contain the same covenants as the Partnership’s other existing Senior Notes.
	In March 2014, in connection with the PVR Acquisition, the Partnership assumed $1.2 billion in aggregate principal amount of PVR’s outstanding senior notes, consisting of $300 million of 8.25% senior notes that mature on April 15, 2018 (the “2018 PVR Notes”), $400 million of 6.5% senior notes that mature on May 15, 2021 (the “2021 PVR Notes”), and $473 million of 8.375% senior notes that mature on June 1, 2020 (the “2020 PVR Notes”). In April 2014, the Partnership redeemed all of the 2018 PVR Notes for $313 million at a price of 104.125% plus accrued and unpaid interest paid to the redemption date. Interest on the 2021 PVR Notes and the 2020 PVR Notes accrue semi-annually on May 15 and November 15 and June 1 and December 1, respectively.
	On March 24, 2014, in accordance with our obligations under the indentures governing the 2020 PVR Notes and the 2021 PVR Notes, we commenced change of control offers pursuant to which holders of such notes were entitled to require us to repurchase all or a portion of their notes at a purchase price of 101% of the principal amount thereof, plus accrued and unpaid interest to the repurchase date. The change of control offers for the 2020 PVR Notes and the 2021 PVR Notes expired on April 22, 2014 and, on April 23, 2014, we accepted for purchase less than $1 million in aggregate principal amount of 2021 PVR Notes.
	In July 2014, the Partnership exchanged $499 million of 8.375% Senior Notes due 2019 (the “Eagle Rock Notes”) of Eagle Rock and Eagle Rock Energy Finance Corp. for 8.375% Senior Notes due 2019 to be issued by the Partnership and Finance Corp. (the “New Partnership Notes”). The New Partnership Notes will have substantially the same economic terms as the outstanding Eagle Rock Notes, including interest rate, interest payment dates, optional redemption terms and maturity. The New Partnership Notes will rank equally with the Partnership’s existing Senior Notes.
	In July 2014, the Partnership and Finance Corp. issued $700 million of senior notes that mature on October 1, 2022 (the “October 2022 Notes”). The October 2022 Notes bear interest at 5% with interest payable semi-annual in arrears on October 1 and April 1, beginning April 1, 2015. At any time prior to July 1, 2022, the Partnership may redeem some or all of the notes at 100% of the principal amount thereof, plus a “make-whole” redemption price and accrued and unpaid interest, if any, to the redemption date. On or after, July 1, 2022, the Partnership may redeem some or all of the notes at a redemption price equal to 100% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date. If the Partnership undergoes certain change of control transactions, it may be required to offer to purchase the notes from holders. The October 2022 Notes are guaranteed by substantially all of the Partnership’s consolidated subsidiaries. In accordance with the terms of the October 2022 Notes, the acquired Eagle Rock entities will become guarantors of the October 2022 Notes within 20 business days of their guarantee of the Partnership’s obligations under the revolving credit facility, which is required to occur within 30 days of the closing of the Eagle Rock Midstream Acquisition. The October 2022 Notes will rank equally in right of payment with all of its existing and future senior unsecured debt, including its other outstanding Senior Notes, and contain substantially the same covenants as its other existing Senior Notes.
	In July 2014, the Partnership redeemed $83 million of the $473 million outstanding 2020 PVR Notes for $91 million, including $8 million of accrued interest and redemption premium.
	At June 30, 2014, the Partnership was in compliance with all material covenants under the Credit Agreement and indentures governing the Senior Notes.
	The Senior Notes issued by the Partnership and Finance Corp. are fully and unconditionally guaranteed, on a joint and several basis, by the Partnership’s existing, 100% owned, consolidated subsidiaries, except for ELG and Aqua - PVR.

Commitments_And_Contingencies_

Commitments And Contingencies (Notes)	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	Commitments and Contingencies
	Legal. The Partnership is involved in various claims, lawsuits and audits by taxing authorities incidental to its business. These claims and lawsuits in the aggregate are not expected to have a material adverse effect on the Partnership’s business, financial condition, results of operations or cash flows.
	PVR Shareholder Litigation. Five putative class action lawsuits challenging the PVR Acquisition are currently pending. All of the cases name PVR, PVR GP and the current directors of PVR GP, as well as the Partnership and the General Partner (collectively, the "Regency Defendants"), as defendants. Each of the lawsuits has been brought by a purported unitholder of PVR, both individually and on behalf of a putative class consisting of public unitholders of PVR. The lawsuits generally allege, among other things, that the directors of PVR GP breached their fiduciary duties to unitholders of PVR, that PVR GP, PVR and the Regency Defendants aided and abetted the directors of PVR GP in the alleged breach of these fiduciary duties, and, as to the actions in federal court, that some or all of PVR, PVR GP, and the directors of PVR GP violated Section 14(a) of the Exchange Act and Rule 14a-9 promulgated thereunder and Section 20(a) of the Exchange Act. The lawsuits purport to seek, in general, (i) injunctive relief, (ii) disclosure of certain additional information concerning the transaction, (iii) in the event the merger is consummated, rescission or an award of rescissory damages, (iv) an award of plaintiffs’ costs and (v) the accounting for damages allegedly causes by the defendants to these actions, and, (iv) such further relief as the court deems just and proper. The styles of the pending cases are as follows: David Naiditch v. PVR Partners, L.P., et al. (Case No. 9015-VCL) in the Court of Chancery of the State of Delaware); Charles Monatt v. PVR Partners, LP, et al. (Case No. 2013-10606) and Saul Srour v. PVR Partners, L.P., et al. (Case No. 2013-011015), each pending in the Court of Common Pleas for Delaware County, Pennsylvania; Stephen Bushansky v. PVR Partners, L.P., et al. (C.A. No. 2:13-cv-06829-HB); and Mark Hinnau v. PVR Partners, L.P., et al. (C.A. No. 2:13-cv-07496-HB), pending in the United States District Court for the Eastern District of Pennsylvania.
	On January 28, 2014, the defendants entered into a Memorandum of Understanding (“MOU”) with Monatt, Srour, Bushansky, Naiditch and Hinnau pursuant to which defendants and the referenced plaintiffs agreed in principle to a settlement of their lawsuits (“Settled Lawsuits”), which will be memorialized in a separate settlement agreement, subject to customary conditions, including consummation of the PVR Acquisition, which occurred on March 21, 2014, completion of certain confirmatory discovery, class certification and final approval by the Court of Common Pleas for Delaware County, Pennsylvania. If the Court approves the settlement, the Settled Lawsuits will be dismissed with prejudice and all defendants will be released from any and all claims relating to the Settled Lawsuits.
	The settlement will not affect any provisions of the merger agreement or the form or amount of consideration received by PVR unitholders in the PVR Acquisition. The defendants have denied and continue to deny any wrongdoing or liability with respect to the plaintiffs’ claims in the aforementioned litigation and have entered into the settlement to eliminate the uncertainty, burden, risk, expense, and distraction of further litigation.
	Utility Line Services, Inc. vs. PVR Marcellus Gas Gathering LLC.  On May 22, 2012, Plaintiff and Counterclaim Defendant, Utility Line Services, Inc. (“ULS”) filed suit against PVR Marcellus Gas Gathering, LLC now known as Regency Marcellus Gas Gathering LLC (“Regency Marcellus”) relating to a dispute involving payment under a construction contract (the “Construction Contract”) entered into in October 2010 for Regency Marcellus’ multi-phase pipeline construction project in Lycoming County, PA (the “Project”). Under the terms of the Construction Contract, Regency Marcellus believed ULS was obligated to design, permit and build Phases I and II of Regency Marcellus’ 30-inch pipeline and to design additional phases of the project. Due to ULS’ deficiencies and delays throughout the project, as well as extensive overbilling for its services, Regency Marcellus allowed the Construction Contract to terminate in accordance with its terms in December 2011 and refused to pay ULS’ outstanding invoices for the Project. ULS then filed suit alleging: Regency Marcellus’ refusal to pay certain invoices totaling approximately $17 million; penalties pursuant to the Pennsylvania Contractor and Subcontractor Payment Act, 73 P.S. § 501, et seq. (“CASPA”), Regency Marcellus’ alleged wrongful withholding of payments owed to ULS; and breach of contract in connection with Regency Marcellus’ alleged wrongful termination of ULS in December 2011. ULS alleged damages, inclusive of CASPA penalties, are in excess of $30 million. Regency Marcellus alleged counterclaims against ULS for breach of the parties’ contract for engineering and construction services; restitution for Regency Marcellus’ overpayments to ULS because of ULS’ improper billing practices; attorneys’ fees resulting from ULS’ meritless claim under CASPA; and professional malpractice against ULS for negligent performance of various engineering services on the Project. Regency Marcellus’ alleged damages exceed $21 million.
	Trial commenced on March 24, 2014 and on April 17, 2014, the jury found in favor of ULS and assessed damages against Regency Marcellus of approximately $24 million plus interest and penalties. In June 2014, ULS and Regency Marcellus reached a settlement in this matter, the terms of which are confidential. The settlement will not have a material adverse effect on the Partnership’s business or financial position.
	Eagle Rock Shareholder Litigation. Three putative class action lawsuits challenging the Eagle Rock Midstream Acquisition are currently pending in federal district court in Houston, Texas. All cases name Eagle Rock and its current directors, as well as the Partnership and a subsidiary, as defendants. One of the lawsuits also names additional Eagle Rock entities as defendants. Each of the lawsuits has been brought by a purported unitholder of Eagle Rock (collectively, the “Plaintiffs”), both individually and on behalf of a putative class consisting of public unitholders of Eagle Rock. The Plaintiffs in each case seek to rescind the transaction, claiming, among other things, that it yields inadequate consideration, was tainted by conflict and constitutes breaches of common law fiduciary duties or contractually imposed duties to the shareholders. Plaintiffs also seek monetary damages and attorneys’ fees. The Partnership and its subsidiary are named as “aiders and abettors” of the allegedly wrongful actions of Eagle Rock and its board.
	Environmental. The Partnership is responsible for environmental remediation at certain sites on its gathering and processing systems, resulting primarily from releases of hydrocarbons. The Partnership’s remediation program typically involves the management of contaminated soils and may involve remediation of groundwater. Activities vary with site conditions and locations, the extent and nature of the contamination, remedial requirements and complexity. The ultimate liability and total costs associated with these sites will depend upon many factors.
	The table below reflects the environmental liabilities recorded at June 30, 2014 and December 31, 2013. Except as described above, the Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		June 30, 2014		December 31, 2013
	Current	$	2	$	2
	Noncurrent	8		6
	Total environmental liabilities	$	10	$	8
	The Partnership recorded less than $1 million in expenditures related to environmental remediation for the six months ended June 30, 2014.
	Endangered Species Act. In March 2014, the U.S. Fish & Wildlife Service listed the lesser prairie chicken as a “threatened” species under the federal Endangered Species Act. This species is predominantly located in the Partnership’s Permian and Midcontinent regions; therefore, the Partnership may encounter additional costs and delays in infrastructure development. The Partnership is participating, along with other companies in our industry, in a conservation plan for this species, which will allow the Partnership to participate in managing the related conservation efforts.
	Air Quality Control. The Partnership is currently negotiating settlements to certain enforcement actions by the NMED and the TCEQ. The TCEQ recently initiated a state-wide emissions inventory for the sulfur dioxide emissions from sites with reported emissions of 10 tons per year or more. If this data demonstrates that any source or group of sources may cause or contribute to a violation of the National Ambient Air Quality Standards, they must be sufficiently controlled to ensure timely attainment of the standard. This may potentially affect three recovery units in Texas. It is unclear at this time how the NMED will address the sulfur dioxide standard.
	Compliance Orders from the NMED. The Partnership has been in discussions with the NMED concerning allegations of violations of New Mexico air regulations related to the Jal #3 and Jal #4 facilities. Hearings on the compliance orders were delayed until October 2014 to allow the parties to pursue substantive settlement discussions. The Partnership has meritorious defenses to the NMED claims and can offer significant mitigating factors to the claimed violations. The Partnership has recorded a liability of less than $1 million related to the claims and will continue to assess its potential exposure to the allegations as the matters progress.
	CDM Sales Tax Audit. CDM Resource Management LLC (“CDM”), a subsidiary of the Partnership, has historically claimed the manufacturing exemption from sales tax in Texas, as is common in the industry. The exemption is based on the fact that CDM’s natural gas compression equipment is used in the process of treating natural gas for ultimate use and sale. In a recent audit by the Texas Comptroller’s office, the Comptroller has challenged the applicability of the manufacturing exemption to CDM. The period being audited is from August 2006 to August 2007, and liability for that period is potentially covered by an indemnity obligation from CDM’s prior owners. CDM may also have liability for periods since 2008, and prospectively, if the Comptroller’s challenge is ultimately successful. An audit of the 2008 period has commenced. In April 2013, an independent audit review agreed with the Comptroller’s position. While CDM continues to disagree with this position and intends to seek redetermination and other relief, we are unable to predict the final outcome of this matter.
	Mine Health and Safety Laws. There are numerous mine health and safety laws and regulations applicable to the coal mining industry. However, since the Partnership does not operate any mines and does not employ any coal miners, it is not subject to such laws and regulations. Accordingly, the Partnership has not accrued any related liabilities.
	In addition to the matters discussed above, the Partnership is involved in legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	As of June 30, 2014 and December 31, 2013, details of the Partnership’s related party receivables and related party payables were as follows:
		June 30, 2014		December 31, 2013
	Related party receivables
	ETE and its subsidiaries	$	17	$	25
	HPC	2		1
	Ranch JV	—		2
	Total related party receivables	$	19	$	28
	Related party payables
	ETE and its subsidiaries	$	39	$	68
	HPC	1		1
	MEP	175		—
	Total related party payables	$	215	$	69
	Transactions with ETE and its subsidiaries. Under the service agreement with Services Co., the Partnership paid Services Co.’s direct expenses for services performed, plus an annual fee of $10 million, and received the benefit of any cost savings recognized for these services. The service agreement has a five year term ending May 26, 2015, subject to earlier termination rights in the event of a change in control, the failure to achieve certain cost savings for the Partnership or upon an event of default. On April 30, 2013, this agreement was amended to provide for a waiver of the $10 million annual fee effective as of May 1, 2013 through and including April 30, 2015 and to clarify the scope and expenses chargeable as direct expenses thereunder.
	On April 30, 2013, the Partnership entered into the second amendment (the “Operation and Service Amendment”) to the Operation and Service Agreement (the “Operation and Service Agreement”), by and among the Partnership, ETC, the General Partner and RGS. Under the Operation and Service Agreement, ETC performs certain operations, maintenance and related services reasonably required to operate and maintain certain facilities owned by the Partnership, and the Partnership reimburses ETC for actual costs and expenses incurred in connection with the provision of these services based on an annual budget agreed upon by both parties. The Operation and Service Agreement Amendment describes the services that ETC will provide in the future.
	The Partnership incurred total service fees related to the agreements described above from ETE and its subsidiaries of $1 million and $2 million for the three months ended June 30, 2014 and 2013, respectively, and $3 million and $7 million for the six months ended June 30, 2014 and 2013, respectively.
	In conjunction with distributions by the Partnership to the limited and general partner interests, ETE received cash distributions of $20 million and $15 million for the three months ended June 30, 2014 and 2013, respectively, and $37 million and $31 million for the six months ended June 30, 2014 and 2013, respectively.
	The Partnership’s Contract Services segment provides contract compression and treating services to subsidiaries of ETE and records revenue in gathering, transportation and other fees. The Partnership’s Contract Services segment purchased compression equipment from a subsidiary of ETE for $22 million and $14 million during the three months ended June 30, 2014 and 2013, respectively, and $31 million and $25 million for the six months ended June 30, 2014 and 2013, respectively.
	Transactions with Lone Star. Subsidiaries of the Partnership have entered into various agreements to sell NGLs to Lone Star. For the six months ended June 30, 2014, the Partnership had recorded $112 million in NGL sales under these contracts of which the unsettled portion are included in the related party receivable from ETE and its subsidiaries.
	Transactions with Southern Union. Prior to April 30, 2013, Southern Union provided certain administrative services for SUGS that were either based on SUGS’s pro-rata share of combined net investment, margin and certain expenses or direct costs incurred by Southern Union on the behalf of SUGS. Southern Union also charged a management and royalty fee to SUGS for certain management support services provided by Southern Union on the behalf of SUGS and for the use of certain Southern Union trademarks, trade names and service marks by SUGS. These administrative services are no longer being provided subsequent to the SUGS Acquisition.
	Transactions with HPC. Under a Master Services Agreement with HPC, the Partnership operates and provides all employees and services for the operation and management of HPC. The related party general and administrative expenses reimbursed to the Partnership were $4 million for the three months ended June 30, 2014 and 2013, and $8 million and $10 million for the six months ended June 30, 2014 and 2013, respectively, which are recorded in gathering, transportation and other fees.
	The Partnership’s Contract Services segment provides compression services to HPC and records revenues in gathering, transportation and other fees. The Partnership also receives transportation services from HPC and records it as cost of sales.

Segment_Information_Notes

Segment Information (Notes)	6 Months Ended
	Jun. 30, 2014
Segment Information [Abstract]	'
Segment Information	'
	Segment Information
	The Partnership has six reportable segments: Gathering and Processing, Natural Gas Transportation, NGL Services, Contract Services, Natural Resources and Corporate. The reportable segments are as described below:
	•	Gathering and Processing. The Partnership provides “wellhead-to-market” services to producers of natural gas, which include transporting raw natural gas from the wellhead through gathering systems, processing raw natural gas to separate NGLs from the raw natural gas and selling or delivering pipeline-quality natural gas and NGLs to various markets and pipeline systems, the gathering of oil (crude and/or condensate, a lighter oil) received from producers, and the gathering and disposing of salt water. This segment also includes ELG, which operates natural gas gathering, oil pipeline, and oil stabilization facilities in south Texas, the Partnership’s 33.33% membership interest in Ranch JV, which processes natural gas delivered from NGL-rich shale formations in west Texas, and the Partnership’s 51% interest in Aqua - PVR, which transports and supplies fresh water to natural gas producers in the Marcellus shale in Pennsylvania. The Partnership completed the SUGS Acquisition on April 30, 2013 which was a reorganization of entities under common control. Therefore, the Gathering and Processing segment amounts have been retrospectively adjusted to reflect the SUGS Acquisition for the three and six months ended June 30, 2013.
	•	Natural Gas Transportation. The Partnership owns a 49.99% general partner interest in HPC, which owns RIGS, a 450- mile intrastate pipeline that delivers natural gas from northwest Louisiana to downstream pipelines and markets, and a 50% membership interest in MEP, which owns a 500-mile interstate natural gas pipeline stretching from southeast Oklahoma through northeast Texas, northern Louisiana and central Mississippi to an interconnect with the Transcontinental Gas Pipe Line system in Butler, Alabama. This segment also includes Gulf States, which owns a 10-mile interstate pipeline that extends from Harrison County, Texas to Caddo Parish, Louisiana.
	•	NGL Services. The Partnership owns a 30% membership interest in Lone Star, an entity owning a diverse set of midstream energy assets including pipelines, storage, fractionation and processing facilities located in Texas, Mississippi and Louisiana.
	•	Contract Services. The Partnership owns and operates a fleet of compressors used to provide turn-key natural gas compression services for customer specific systems. The Partnership also owns and operates a fleet of equipment used to provide treating services, such as carbon dioxide and hydrogen sulfide removal, natural gas cooling, dehydration and BTU management.
	•	Natural Resources. The Partnership is involved in the management of coal and natural resources properties and the related collection of royalties. The Partnership also earns revenues from other land management activities, such as selling standing timber, leasing coal-related infrastructure facilities, and collecting oil and gas royalties. This segment also includes the Partnership’s 50% interest in Coal Handling, which owns and operates end-user coal handling facilities.
	•	Corporate. The Corporate segment comprises the Partnership’s corporate assets.
	The Partnership accounts for intersegment revenues as if the revenues were to third parties, exclusive of certain cost of capital charges.
	Management evaluates the performance of each segment and makes capital allocation decisions through the separate consideration of segment margin and operation and maintenance expenses. Segment margin for the Gathering and Processing and the Natural Gas Transportation segments is defined as total revenues, including service fees, less cost of sales. In the Contract Services segment, segment margin is defined as revenues less direct costs. The Natural Resources segment margin is generally equal to total revenues as there is typically minimal cost of sales associated with the management and leasing of properties.
	Management believes segment margin is an important measure because it directly relates to volume, commodity price changes and revenue generating horsepower. Operation and maintenance expenses are a separate measure used by management to evaluate performance of field operations. Direct labor, insurance, property taxes, repair and maintenance, utilities and contract services comprise the most significant portion of operation and maintenance expenses. These expenses fluctuate depending on the activities performed during a specific period. The Partnership does not deduct operation and maintenance expenses from total revenues in calculating segment margin because management separately evaluates commodity volume and price changes in segment margin. The Partnership does not record segment margin for its investments in unconsolidated affiliates (HPC, MEP, Lone Star, Ranch JV, Aqua - PVR, and Coal Handling) because it records its ownership percentages of their net income as income from unconsolidated affiliates in accordance with the equity method of accounting.
	Results for each segment are shown below:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	External Revenues
	Gathering and Processing	$	1,074		$	583		$	1,867		$	1,069
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	78			52			141			101
	Natural Resources	20			—			22			—
	Corporate	6			4			11			9
	Eliminations	—			—			—			—
	Total	$	1,178		$	639		$	2,041		$	1,179
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	4			4			8			7
	Natural Resources	—			—			—			—
	Corporate	—			—			—			—
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	269		$	145		$	435		$	248
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	63			49			119			97
	Natural Resources	20			—			22			—
	Corporate	2			4			7			9
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	350		$	194		$	575		$	347
	Operation and Maintenance
	Gathering and Processing	$	71		$	60		$	132		$	114
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	21			17			41			35
	Natural Resources	5			—			5			—
	Corporate	—			—			1			—
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	93		$	73		$	171		$	142
	The table below provides a reconciliation of total segment margin to (loss) income before income taxes:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Total segment margin	$	350		$	194		$	575		$	347
	Operation and maintenance	(93		)	(73		)	(171		)	(142		)
	General and administrative	(54		)	(18		)	(87		)	(51		)
	Gain (loss) on asset sales, net	—			(1		)	2			(2		)
	Depreciation, depletion and amortization	(168		)	(68		)	(262		)	(133		)
	Income from unconsolidated affiliates	47			31			90			66
	Interest expense, net	(78		)	(41		)	(134		)	(78		)
	Loss on debt refinancing, net	—			(7		)	—			(7		)
	Other income and deductions, net	(7		)	(7		)	(5		)	(21		)
	(Loss) income before income taxes	$	(3	)	$	10		$	8		$	(21	)
The tables below provide amounts reflected in the condensed consolidated balance sheets for each segment:
Total Assets	June 30, 2014			December 31, 2013
Gathering and Processing	$	10,285		$	4,748
Natural Gas Transportation	1,144			991
NGL Services	1,135			1,070
Contract Services	2,007			1,897
Natural Resources	514			—
Corporate	374			76
Total	$	15,459		$	8,782
Investment in Unconsolidated Affiliates	June 30, 2014			December 31, 2013
Gathering and Processing	$	89		$	36
Natural Gas Transportation	1,143			991
NGL Services	1,135			1,070
Natural Resources	11			—
Total	$	2,378		$	2,097

EquityBased_Compensation_Notes

Equity-Based Compensation (Notes)	6 Months Ended
	Jun. 30, 2014
Equity-Based Compensation [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	The Partnership’s LTIP for its employees, directors and consultants authorizes grants up to 5,865,584 common units. LTIP compensation expense of $3 million and $1 million was recorded in general and administrative expense for the three months ended June 30, 2014 and 2013, respectively, and $5 million and $3 million for the six months ended June 30, 2014 and 2013, respectively.
	Phantom Units. Phantom units granted during the period were service condition grants that (1) have graded vesting over five years or (2) vest over the next five years on a cliff basis; by vesting 60% at the end of the third year of service and vesting the remaining 40% at the end of the fifth year of service. Distributions related to the unvested phantom units are paid concurrent with the Partnership’s distribution for common units.
	The following table presents phantom units activity for the six months ended June 30, 2014:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	982,242		$	23.16
	Service condition grants	718,791		25.99
	Vested service condition	(4,008	)	26.53
	Forfeited service condition	(72,185	)	24.77
	Outstanding at end of period	1,624,840		$	24.33
	The Partnership expects to recognize $30 million of compensation expense related to non-vested phantom units over a weighted-average period of 3.7 years.

Fair_Value_Measures_Notes

Fair Value Measures (Notes)	6 Months Ended
	Jun. 30, 2014
Fair Value Measures [Abstract]	'
Fair Value Measures	'
	Fair Value Measures
	The Partnership’s financial assets and liabilities measured at fair value on a recurring basis are derivatives related to commodity swaps and embedded derivatives in the Series A Preferred Units. Derivatives related to commodity swaps are valued using discounted cash flow techniques. These techniques incorporate Level 1 and Level 2 inputs such as commodity prices. These market inputs are utilized in the discounted cash flow calculation considering the instrument’s term, notional amount, discount rate and credit risk and are classified as Level 2 in the hierarchy. Embedded derivatives related to Series A Preferred Units are valued using a binomial lattice model. The inputs utilized in the model include credit spread, probabilities of the occurrence of certain events, common unit price, dividend yield, and expected volatility, and are classified as Level 3 in the hierarchy.
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurements at June 30, 2014							Fair Value Measurements at December 31, 2013
		Fair Value Total			Significant		Unobservable		Fair Value Total		Significant		Unobservable
					Observable		Inputs				Observable		Inputs
					Inputs		(Level 3)				Inputs		(Level 3)
					(Level 2)						(Level 2)
	Assets
	Commodity Derivatives:
	Natural Gas	$	1		$	1	$	—	$	2	$	2	$	—
	NGLs	1			1		—		2		2		—
	Total Assets	$	2		$	2	$	—	$	4	$	4	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	5		$	5	$	—	$	4	$	4	$	—
	NGLs	2			2		—		4		4		—
	Condensate	4			4		—		1		1		—
	Embedded derivatives in Series A Preferred Units	29			—		29		19		—		19
	Total Liabilities	$	40		$	11	$	29	$	28	$	9	$	19
	The following table presents the material unobservable inputs used to estimate the fair value of the embedded derivatives in the Series A Preferred Units:
	Unobservable Input		June 30, 2014
	Credit Spread		3.91	%
	Volatility		21.4	%
	Changes in the Partnership’s cost of equity and U.S. Treasury yields would cause a change in the credit spread used to value the embedded derivatives. Changes in the Partnership’s historical unit price volatility would cause a change in the volatility used to value the embedded derivatives.
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the six months ended June 30, 2014. There were no transfers between the fair value hierarchy levels for the six months ended June 30, 2014.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2013	$	19
	Change in fair value	10
	Net liability balance at June 30, 2014	$	29
	The carrying amount of cash and cash equivalents, accounts receivable and accounts payable approximates fair value due to their short-term maturities. Long-term debt, other than the Senior Notes, is comprised of borrowings under which interest accrues under a floating interest rate structure. Accordingly, the carrying value approximates fair value.
	The aggregate fair value and carrying amount of the Senior Notes at June 30, 2014 were $4.9 billion and $4.57 billion, respectively. As of December 31, 2013, the aggregate fair value and carrying amount of the Senior Notes were $2.83 billion and $2.80 billion, respectively. The fair value of the Senior Notes is a Level 1 valuation based on third party market value quotations.

Consolidating_Guarantor_Financ

Consolidating Guarantor Financial Information (Notes)	6 Months Ended
	Jun. 30, 2014
Statement of Financial Position [Abstract]	'
Guarantees [Text Block]	'
	Consolidating Guarantor Financial Information
	ELG and Aqua - PVR do not fully and unconditionally guarantee, on a joint and several basis, the Senior Notes issued and outstanding as of June 30, 2014, by the Partnership and Finance Corp.. Included in the Parent financial statements are the Partnership’s intercompany investments in all consolidated subsidiaries and the Partnership’s investments in unconsolidated subsidiaries. ELG and Aqua - PVR are included in the non-guarantor subsidiaries.
	The consolidating financial information for the Parent, Guarantor Subsidiaries, and Non Guarantor Subsidiaries are as follows:
		30-Jun-14
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	15		$	43		$	(8	)	$	50
	Intercompany accounts receivable	—			—			—			—			—
	All other current assets	—			538			5			(1		)	542
	Property, plant, and equipment, net	—			7,236			269			(89		)	7,416
	Investment in subsidiaries	18,368			—			—			(18,368		)	—
	Investment in unconsolidated subsidiaries	—			2,221			—			157			2,378
	All other assets	—			5,073			—			—			5,073
	TOTAL ASSETS	$	18,368		$	15,083		$	317		$	(18,309	)	$	15,459
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	Intercompany accounts payable	$	—		$	—		$	—		$	—		$	—
	All other current liabilities	—			722			8			—			730
	Long-term liabilities	4,673			937			3			(3		)	5,610
	Noncontrolling interest	—			—			—			107			107
	Total partners’ capital	13,695			13,424			306			(18,413		)	9,012
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	18,368		$	15,083		$	317		$	(18,309	)	$	15,459
		31-Dec-13
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	19		$	—		$	19
	Intercompany accounts receivable	—			615			—			(615		)	—
	All other current assets	—			366			15			—			381
	Property, plant, and equipment, net	—			4,244			174			—			4,418
	Investment in subsidiaries	10,446			—			—			(10,446		)	—
	Investment in unconsolidated subsidiaries	—			1,995			—			102			2,097
	All other assets	—			1,867			—			—			1,867
	TOTAL ASSETS	$	10,446		$	9,087		$	208		$	(10,959	)	$	8,782
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	Intercompany accounts payable	$	—		$	615		$	—		$	(615	)	$	—
	All other current liabilities	—			466			9			—			475
	Long-term liabilities	2,832			559			—			—			3,391
	Noncontrolling interest	—			—			—			102			102
	Total partners’ capital	7,614			7,447			199			(10,446		)	4,814
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	10,446		$	9,087		$	208		$	(10,959	)	$	8,782
		Three Months Ended June 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,162		$	16		$	—		$	1,178
	Operating costs, expenses, and other	—			1,137			9			(3		)	1,143
	Operating income	—			25			7			3			35
	Income from unconsolidated affiliates	—			48			—			(1		)	47
	Interest expense, net	(71		)	(7		)	—			—			(78		)
	Gain (loss) on debt refinancing, net	1			(1		)	—			—			—
	Equity in consolidated subsidiaries	73			—			—			(73		)	—
	Other income and deductions, net	(8		)	1			—			—			(7		)
	(Loss) income before income taxes	(5		)	66			7			(71		)	(3		)
	Income tax expense	1			—			—			—			1
	Net (loss) income	(6		)	66			7			(71		)	(4		)
	Net income attributable to noncontrolling interest	—			—			—			(4		)	(4		)
	Net (loss) income attributable to Regency Energy Partners LP	$	(6	)	$	66		$	7		$	(75	)	$	(8	)
	Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
	Comprehensive (loss) income	(6		)	66			7			(71		)	(4		)
	Comprehensive income attributable to noncontrolling interest	—			—			—			4			4
	Comprehensive (loss) income attributable to Regency Energy Partners LP	$	(6	)	$	66		$	7		$	(75	)	$	(8	)
		Three Months Ended June 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	635		$	4		$	—		$	639
	Operating costs, expenses, and other	—			602			3			—			605
	Operating income	—			33			1			—			34
Income from unconsolidated affiliates	—			31			—			—			31
Interest expense, net	(36		)	(5		)	—			—			(41		)
Loss on debt refinancing, net	(7		)	—			—			—			(7		)
Equity in consolidated subsidiaries	62			—			—			(62		)	—
Other income and deductions, net	(8		)	1			—			—			(7		)
Income before income taxes	11			60			1			(62		)	10
Income tax benefit	—			(1		)	—			—			(1		)
Net income	11			61			1			(62		)	11
Net income attributable to noncontrolling interest	—			—			—			(1		)	(1		)
Net income attributable to Regency Energy Partners LP	$	11		$	61		$	1		$	(63	)	$	10
Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
Comprehensive income	11			61			1			(62		)	11
Comprehensive income attributable to noncontrolling interest	—			—			—			1			1
Comprehensive income attributable to Regency Energy Partners LP	$	11		$	61		$	1		$	(63	)	$	10
	Six Months Ended June 30, 2014
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Revenues	$	—		$	2,011		$	31		$	(1	)	$	2,041
Operating costs, expenses, and other	—			1,972			15			(3		)	1,984
Operating income	—			39			16			2			57
Income from unconsolidated affiliates	—			91			—			(1		)	90
Interest expense, net	(121		)	(13		)	—			—			(134		)
Gain (loss) on debt refinancing, net	1			(1		)	—			—			—
Equity in consolidated subsidiaries	137			—			—			(137		)	—
Other income and deductions, net	(9		)	4			—			—			(5		)
Income before income taxes	8			120			16			(136		)	8
Income tax expense (benefit)	1			(2		)	1			—			—
Net income	7			122			15			(136		)	8
Net income attributable to noncontrolling interest	—			—			—			(7		)	(7		)
Net income attributable to Regency Energy Partners LP	$	7		$	122		$	15		$	(143	)	$	1
Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
Comprehensive income	7			122			15			(136		)	8
Comprehensive income attributable to noncontrolling interest	—			—			—			7			7
Comprehensive income attributable to Regency Energy Partners LP	$	7		$	122		$	15		$	(143	)	$	1
	Six Months Ended June 30, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Revenues	$	—		$	1,171		$	8		$	—		$	1,179
Operating costs, expenses, and other	3			1,152			5			—			1,160
Operating (loss) income	(3		)	19			3			—			19
Income from unconsolidated affiliates	—			66			—			—			66
Interest expense, net	(69		)	(9		)	—			—			(78		)
Loss on debt refinancing, net	(7		)	—			—			—			(7		)
Equity in consolidated subsidiaries	83			—			—			(83		)	—
Other income and deductions, net	(22		)	1			—			—			(21		)
(Loss) income before income taxes	(18		)	77			3			(83		)	(21		)
Income tax benefit	—			(3		)	—			—			(3		)
Net (loss) income	(18		)	80			3			(83		)	(18		)
Net income attributable to noncontrolling interest	—			—			—			(1		)	(1		)
Net (loss) income attributable to Regency Energy Partners LP	$	(18	)	$	80		$	3		$	(84	)	$	(19	)
Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
Comprehensive (loss) income	(18		)	80			3			(83		)	(18		)
Comprehensive income attributable to noncontrolling interest	—			—			—			1			1
Comprehensive (loss) attributable to Regency Energy Partners LP	$	(18	)	$	80		$	3		$	(84	)	$	(19	)
	Six Months Ended June 30, 2014
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Cash flows from operating activities	$	—		$	243		$	35		$	(1	)	$	277
Cash flows from investing activities	—			(657		)	(5		)	(8		)	(670		)
Cash flows from financing activities	—			429			(6		)	1			424
Change in cash	—			15			24			(8		)	31
Cash at beginning of period	—			—			19			—			19
Cash at end of period	$	—		$	15		$	43		$	(8	)	$	50
	Six Months Ended June 30, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Cash flows from operating activities	$	—		$	185		$	10		$	—		$	195
Cash flows from investing activities	—			(882		)	(76		)	—			(958		)
Cash flows from financing activities	—			697			30			—			727
Change in cash	—			—			(36		)	—			(36		)
Cash at beginning of period	—			—			53			—			53
Cash at end of period	$	—		$	—		$	17		$	—		$	17

Organization_And_Summary_Of_Si1

Organization And Summary Of Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2014
Organization And Summary Of Significant Accounting Policies	'
Organization And Basis Of Presentation	'
	Organization. The unaudited condensed consolidated financial statements presented herein contain the results of Regency Energy Partners LP and its subsidiaries (the “Partnership”), a Delaware limited partnership. The Partnership and its subsidiaries are engaged in the business of gathering and processing, compression, treating and transportation of natural gas; the transportation, fractionation and storage of NGLs; the gathering, transportation and terminaling of oil (crude and/or condensate, a lighter oil) received from producers; and the management of coal and natural resource properties in the United States. Regency GP LP is the Partnership’s general partner and Regency GP LLC (collectively the “General Partner”) is the managing general partner of the Partnership and the general partner of Regency GP LP.
Basis of Presentation and Significant Accounting Policies [Text Block]	'
	Basis of Presentation. The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2013. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All inter-company items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
Use Of Estimates	'
	Use of Estimates. The unaudited condensed consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
Equity Method Investments, Policy [Policy Text Block]	'
	Equity Method Investments. Even though there is a presumption of a controlling financial interest in Aqua - PVR (because of our 51% ownership), our partner in this joint venture has substantive participating rights and management authority that preclude us from controlling the joint venture. Therefore, it is accounted for as an equity method investment.
Revenue Recognition, Services, Royalty Fees [Policy Text Block]	'
	Coal Royalties Revenues and Deferred Income. The Partnership recognizes coal royalties revenues on the basis of tons of coal sold by its lessees and the corresponding revenues from those sales. The Partnership does not have access to actual production and revenues information until 30 days following the month of production. Therefore, financial results include estimated revenues and accounts receivable for the month of production. The Partnership records any differences between the actual amounts ultimately received or paid and the original estimates in the period they become finalized. Most lessees must make minimum monthly or annual payments that are generally recoverable over certain time periods. These minimum payments are recorded as deferred income. If the lessee recovers a minimum payment through production, the deferred income attributable to the minimum payment is recognized as coal royalties revenues. If a lessee fails to meet its minimum production for certain pre-determined time periods, the deferred income attributable to the minimum payment is recognized as minimum rental revenues, which is a component of other revenues on our consolidated statements of operations. Other liabilities on the balance sheet also include deferred unearned income from a coal services facility lease, which is recognized as other income as it is earned.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	New Accounting Pronouncement. In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. The Partnership is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies.

Organization_And_Summary_Of_Si2

Organization And Summary Of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Organization And Summary Of Significant Accounting Policies	'
Revenue by Combined Entity [Table Text Block]	'
	The following table presents the revenues and net income for the previously separate entities and the combined amounts presented herein:
		Three Months Ended June 30, 2013			Six Months Ended June 30, 2013 (1)
	Revenues:
	Partnership	$	562		$	911
	SUGS	77			268
	Combined	$	639		$	1,179
	Net income (loss):
	Partnership	$	20		$	15
	SUGS	(9		)	(33		)
	Combined	$	11		$	(18	)
	(1) The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include one month and four months of activity for the three months and six months ended June 30, 2013, respectively.

Partners_Capital_and_Distribut1

Partners' Capital and Distributions (Tables)	6 Months Ended
	Jun. 30, 2014
Partners’ Capital and Distributions [Abstract]	'
Schedule of Stockholders Equity [Table Text Block]	'
	The change in common and Class F units during the six months ended June 30, 2014 was as follows:
		Common		Class F
	Balance - December 31, 2013	210,850,232		6,274,483
	Issuance of common units under LTIP, net of forfeitures and tax withholding	24,808		—
	Issuance of common units under the equity distribution agreements	2,374,397		—
	Issuance of common units in connection with Hoover Acquisition	4,040,471		—
	Issuance of common units in connection with PVR Acquisition	140,388,382		—
	Issuance of common units to ETE Common Holdings	14,398,848		—
	Balance - June 30, 2014	372,077,138		6,274,483
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	'
	Following are distributions declared by the Partnership subsequent to December 31, 2013:
	Quarter Ended		Record Date	Payment Date	Cash Distributions
					(per common unit)
	December 31, 2013		February 7, 2014	February 14, 2014	$0.48
	March 31, 2014		May 8, 2014	May 15, 2014	$0.48
	June 30, 2014		August 7, 2014	August 14, 2014	$0.49

Loss_Income_Per_Limited_Partne1

(Loss) Income Per Limited Partner Unit (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Basic And Diluted Income (Loss) From Continuing Operations	'
	The following tables provide a reconciliation of the numerator and denominator of the basic and diluted earnings per common unit computations for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30,
		2014									2013
		Loss				Units		Per-Unit			Income		Units	Per-Unit
		(Numerator)				(Denominator)		Amount			(Numerator)		(Denominator)	Amount
	Basic (loss) income per unit
	Amount allocated to common units	$	(18	)		361,071,005		$	(0.05	)	$	13	193,065,183	$	0.07
	Effect of Dilutive Securities:
	Common unit options	—				—					—		24,365
	Phantom units	—				—					—		331,462
	Diluted (loss) income per unit	$	(18	)		361,071,005		$	(0.05	)	$	13	193,421,010	$	0.07
		Six Months Ended June 30,
		2014									2013
		Loss				Units		Per-Unit			Income		Units	Per-Unit
		(Numerator)				(Denominator)		Amount			(Numerator)		(Denominator)	Amount
	Basic (loss) income per unit
	Amount allocated to common units	$	(17	)		293,931,615		$	(0.06	)	$	4	182,070,077	$	0.02
	Effect of Dilutive Securities:
	Common unit options	—				—					—		19,035
	Phantom units	—				—					—		303,218
	Diluted (loss) income per unit	$	(17	)		293,931,615		$	(0.06	)	$	4	182,392,330	$	0.02
Weighted Average Outstanding Amount Of Securities	'
	The following data show securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit because to do so would have been antidilutive for the periods presented:
		Three Months Ended June 30,					Six Months Ended June 30,
		2014			2013		2014			2013
	Common unit options	25,165			—		24,188			—
	Phantom units	580,935			—		505,235			—
	Series A Preferred Units	2,057,662			4,672,835		2,055,949			4,672,835

Acquisitions_Tables

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2014
Business Acquisition, Pro Forma Information [Table Text Block]	'
	The following unaudited pro forma consolidated results of operations for the three and six months ended June 30, 2014 and 2013 are presented as if the PVR and Hoover acquisitions had been completed on January 1, 2013. The pro forma information includes adjustments to reflect incremental expenses associated with the fair value adjustments recorded as a result of applying the acquisition method of accounting and incremental interest expense related to the financing of a portion of the purchase price. This pro forma information is not necessarily indicative of the results that would have occurred had the acquisitions occurred on January 1, 2013, nor is it indicative of future results of operations.
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Revenues	$	1,178		$	923		$	2,323		$	1,731
	Net loss attributable to the Partnership	(18		)	(20		)	(53		)	(78		)
	Basic net loss per Limited Partner unit	$	(0.05	)	$	(0.07	)	$	(0.16	)	$	(0.27	)
	Diluted net loss per Limited Partner unit	$	(0.05	)	$	(0.07	)	$	(0.16	)	$	(0.27	)
PVR [Member]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	Management is in the process of finalizing the evaluation of the assigned fair values to the assets acquired and liabilities assumed. The total purchase was allocated as follows:
	Assets	At March 21, 2014
	Current assets	$	140
	Gathering and transmission systems	1,396
	Compression equipment	342
	Gas plants and buildings	110
	Natural resources	454
	Other property, plant and equipment	229
	Construction in process	172
	Investment in unconsolidated subsidiaries	62
	Intangible assets	2,717
	Goodwill (1)	353
	Other long-term assets	18
	Total Assets Acquired	$	5,993
	Liabilities
	Current liabilities	$	161
	Long-term debt	1,788
	Premium related to senior notes	99
	Long-term liabilities	42
	Total Liabilities Assumed	$	2,090
	Net Assets Acquired	$	3,903
Hoover Energy [Member]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	Management completed the evaluation of the assigned fair values to the assets acquired and liabilities assumed. The total purchase price was allocated as follows:
	Assets	At February 3, 2014
	Accounts receivable, net	$	5
	Gathering and transmission systems	72
	Compression equipment	15
	Other property, plant, and equipment	22
	Construction in process	6
	Intangible assets	148
	Goodwill (1)	30
	Total Assets Acquired	$	298
	Liabilities
	Accounts payable and accrued liabilities	$	5
	Asset retirement obligation	2
	Total Liabilities Assumed	$	7
	Net Assets Acquired	$	291

Investment_In_Unconsolidated_A1

Investment In Unconsolidated Affiliates (Tables)	6 Months Ended
	Jun. 30, 2014
Carrying value of limited and general partnership interest	'
	The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of June 30, 2014 and December 31, 2013 is as follows:
		June 30, 2014			December 31, 2013
	HPC	$	434		$	442
	MEP	709			548
	Lone Star	1,135			1,070
	Ranch JV	39			36
	Aqua - PVR	50			—
	Coal Handling	11			—
	Grey Ranch	—			1
	Total	$	2,378		$	2,097
Changes In The Partnership's Investment	'
	The following tables summarize the Partnership’s investment activities in each of the unconsolidated affiliates for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	44		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(11		)	(19		)	(32		)	(1		)	—			—
	Share of earnings of unconsolidated affiliates’ net income (loss)	8			12			27			3			(1		)	—
	Amortization of excess fair value of investment	(2		)	—			—			—			—			—
		Three Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	22		$	—
	Distributions from unconsolidated affiliates	(14		)	(18		)	(23		)	—
	Share of earnings of unconsolidated affiliates’ net income	9			10			13			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Six Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	71		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(21		)	(37		)	(57		)	(1		)	—			—
	Share of earnings of unconsolidated affiliates’ net income (loss)	16			22			51			5			(1		)	—
	Amortization of excess fair value of investment	(3		)	—			—			—			—			—
		Six Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	49		$	1
	Distributions from unconsolidated affiliates	(30		)	(38		)	(40		)	—
	Share of earnings of unconsolidated affiliates’ net income	19			20			30			—
	Amortization of excess fair value of investment	(3		)	—			—			—
Condensed Consolidated Income Statements	'
	The following tables present selected income statement data for each of the unconsolidated affiliates, on a 100% basis, for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	37		$	66		$	880		$	11		$	1		$	3
	Operating income (loss)	20			35			90			7			(3		)	1
	Net income (loss)	16			23			89			8			(2		)	1
		Three Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	63		$	425		$	3
	Operating income	19			33			45			1
	Net income	18			21			44			1
		Six Months Ended June 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	74		$	132		$	1,693		$	20		$	1		$	3
	Operating income (loss)	38			69			174			14			(3		)	1
	Net income (loss)	31			44			172			14			(2		)	1
		Six Months Ended June 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	78		$	128		$	783		$	6
	Operating income	39			67			101			1
	Net income	38			42			99			1

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments [Abstract]	'
Schedule Of Derivative Assets And Liabilities Statement	'
	The Partnership’s derivative assets and liabilities, including credit risk adjustments, as of June 30, 2014 and December 31, 2013 are detailed below:
		Assets						Liabilities
		June 30, 2014			December 31, 2013			June 30, 2014		December 31, 2013
	Derivatives not designated as cash flow hedges
	Current amounts
	Commodity contracts	$	2		$	3		$	11	$	9
	Long-term amounts
	Commodity contracts	—			1			—		—
	Embedded derivatives in Series A Preferred Units	—			—			29		19
	Total derivatives	$	2		$	4		$	40	$	28
Derivative Instruments, Gain (Loss) [Table Text Block]	'
	The Partnership’s statements of operations for the three and six months ended June 30, 2014 and 2013 were impacted by derivative instruments activities as follows:
				Three Months Ended June 30,
				2014			2013
	Derivatives not designated in a hedging relationship		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(5	)	$	14
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(9		)	(8		)
				$	(14	)	$	6
				Six Months Ended June 30,
				2014			2013
	Derivatives not designated in a hedging relationship		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(18	)	$	11
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(10		)	(22		)
				$	(28	)	$	(11	)

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Long-Term Debt Disclosure [Abstract]	'
Partnership's Long-Term Debt	'
	Obligations in the form of senior notes and borrowings under the revolving credit facility are as follows:
		June 30, 2014			December 31, 2013
	Senior notes	$	4,572		$	2,800
	Revolving loans	850			510
	Unamortized premium and discounts	68			—
	Long-term debt	$	5,490		$	3,310
	Availability under revolving credit facility:
	Total credit facility limit	$	1,500		$	1,200
	Revolving loans	(850		)	(510		)
	Letters of credit	(28		)	(14		)
	Total available	$	622		$	676
Long-Term Debt Maturities	'
	Long-term debt maturities as of June 30, 2014 for each of the next five years are as follows:
	Years Ending December 31,		Amount
	2014 (remainder)		$	—
	2015		—
	2016		—
	2017		—
	2018		600
	Thereafter		4,822
	Total *		$	5,422
	*	Excludes a $82 million unamortized premium on the PVR senior notes assumed by the Partnership and a $14 million unamortized discount on the 2022 Notes.

Commitments_And_Contingencies_1

Commitments And Contingencies (Tables)	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	The table below reflects the environmental liabilities recorded at June 30, 2014 and December 31, 2013. Except as described above, the Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		June 30, 2014		December 31, 2013
	Current	$	2	$	2
	Noncurrent	8		6
	Total environmental liabilities	$	10	$	8

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions [Table Text Block]	'
	As of June 30, 2014 and December 31, 2013, details of the Partnership’s related party receivables and related party payables were as follows:
		June 30, 2014		December 31, 2013
	Related party receivables
	ETE and its subsidiaries	$	17	$	25
	HPC	2		1
	Ranch JV	—		2
	Total related party receivables	$	19	$	28
	Related party payables
	ETE and its subsidiaries	$	39	$	68
	HPC	1		1
	MEP	175		—
	Total related party payables	$	215	$	69

Segment_Information_Tables

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Information [Abstract]	'
Operating Results for Each Segment	'
	Results for each segment are shown below:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	External Revenues
	Gathering and Processing	$	1,074		$	583		$	1,867		$	1,069
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	78			52			141			101
	Natural Resources	20			—			22			—
	Corporate	6			4			11			9
	Eliminations	—			—			—			—
	Total	$	1,178		$	639		$	2,041		$	1,179
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	4			4			8			7
	Natural Resources	—			—			—			—
	Corporate	—			—			—			—
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	269		$	145		$	435		$	248
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	63			49			119			97
	Natural Resources	20			—			22			—
	Corporate	2			4			7			9
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	350		$	194		$	575		$	347
	Operation and Maintenance
	Gathering and Processing	$	71		$	60		$	132		$	114
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	21			17			41			35
	Natural Resources	5			—			5			—
	Corporate	—			—			1			—
	Eliminations	(4		)	(4		)	(8		)	(7		)
	Total	$	93		$	73		$	171		$	142
Reconciliation of Total Segment Margin to Income (Loss) Before Income Taxes	'
	The table below provides a reconciliation of total segment margin to (loss) income before income taxes:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Total segment margin	$	350		$	194		$	575		$	347
	Operation and maintenance	(93		)	(73		)	(171		)	(142		)
	General and administrative	(54		)	(18		)	(87		)	(51		)
	Gain (loss) on asset sales, net	—			(1		)	2			(2		)
	Depreciation, depletion and amortization	(168		)	(68		)	(262		)	(133		)
	Income from unconsolidated affiliates	47			31			90			66
	Interest expense, net	(78		)	(41		)	(134		)	(78		)
	Loss on debt refinancing, net	—			(7		)	—			(7		)
	Other income and deductions, net	(7		)	(7		)	(5		)	(21		)
	(Loss) income before income taxes	$	(3	)	$	10		$	8		$	(21	)
Schedule Of Assets Related To Balance Sheet	'
	The tables below provide amounts reflected in the condensed consolidated balance sheets for each segment:
	Total Assets	June 30, 2014			December 31, 2013
	Gathering and Processing	$	10,285		$	4,748
	Natural Gas Transportation	1,144			991
	NGL Services	1,135			1,070
	Contract Services	2,007			1,897
	Natural Resources	514			—
	Corporate	374			76
	Total	$	15,459		$	8,782
	Investment in Unconsolidated Affiliates	June 30, 2014			December 31, 2013
	Gathering and Processing	$	89		$	36
	Natural Gas Transportation	1,143			991
	NGL Services	1,135			1,070
	Natural Resources	11			—
	Total	$	2,378		$	2,097

EquityBased_Compensation_Table

Equity-Based Compensation (Tables) (Phantom Units)	6 Months Ended
	Jun. 30, 2014
Phantom Units	'
Phantom Units Activity	'
	The following table presents phantom units activity for the six months ended June 30, 2014:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	982,242		$	23.16
	Service condition grants	718,791		25.99
	Vested service condition	(4,008	)	26.53
	Forfeited service condition	(72,185	)	24.77
	Outstanding at end of period	1,624,840		$	24.33

Fair_Value_Measures_Tables

Fair Value Measures (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Measures [Abstract]	'
FV of Partnership's Derivative Assets and Liabilities	'
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurements at June 30, 2014							Fair Value Measurements at December 31, 2013
		Fair Value Total			Significant		Unobservable		Fair Value Total		Significant		Unobservable
					Observable		Inputs				Observable		Inputs
					Inputs		(Level 3)				Inputs		(Level 3)
					(Level 2)						(Level 2)
	Assets
	Commodity Derivatives:
	Natural Gas	$	1		$	1	$	—	$	2	$	2	$	—
	NGLs	1			1		—		2		2		—
	Total Assets	$	2		$	2	$	—	$	4	$	4	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	5		$	5	$	—	$	4	$	4	$	—
	NGLs	2			2		—		4		4		—
	Condensate	4			4		—		1		1		—
	Embedded derivatives in Series A Preferred Units	29			—		29		19		—		19
	Total Liabilities	$	40		$	11	$	29	$	28	$	9	$	19
Significant Unobservable Inputs for FV Estimation of Embedded Derivatives	'
	The following table presents the material unobservable inputs used to estimate the fair value of the embedded derivatives in the Series A Preferred Units:
	Unobservable Input		June 30, 2014
	Credit Spread		3.91	%
	Volatility		21.4	%
Valuation Changes in Level 3 Derivatives	'
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the six months ended June 30, 2014. There were no transfers between the fair value hierarchy levels for the six months ended June 30, 2014.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2013	$	19
	Change in fair value	10
	Net liability balance at June 30, 2014	$	29

Consolidating_Guarantor_Financ1

Consolidating Guarantor Financial Information (Tables)	6 Months Ended
	Jun. 30, 2014
Statement of Financial Position [Abstract]	'
Condensed Balance Sheet [Table Text Block]	'
	The consolidating financial information for the Parent, Guarantor Subsidiaries, and Non Guarantor Subsidiaries are as follows:
		30-Jun-14
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	15		$	43		$	(8	)	$	50
	Intercompany accounts receivable	—			—			—			—			—
	All other current assets	—			538			5			(1		)	542
	Property, plant, and equipment, net	—			7,236			269			(89		)	7,416
	Investment in subsidiaries	18,368			—			—			(18,368		)	—
	Investment in unconsolidated subsidiaries	—			2,221			—			157			2,378
	All other assets	—			5,073			—			—			5,073
	TOTAL ASSETS	$	18,368		$	15,083		$	317		$	(18,309	)	$	15,459
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	Intercompany accounts payable	$	—		$	—		$	—		$	—		$	—
	All other current liabilities	—			722			8			—			730
	Long-term liabilities	4,673			937			3			(3		)	5,610
	Noncontrolling interest	—			—			—			107			107
	Total partners’ capital	13,695			13,424			306			(18,413		)	9,012
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	18,368		$	15,083		$	317		$	(18,309	)	$	15,459
		31-Dec-13
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	19		$	—		$	19
	Intercompany accounts receivable	—			615			—			(615		)	—
	All other current assets	—			366			15			—			381
	Property, plant, and equipment, net	—			4,244			174			—			4,418
	Investment in subsidiaries	10,446			—			—			(10,446		)	—
	Investment in unconsolidated subsidiaries	—			1,995			—			102			2,097
	All other assets	—			1,867			—			—			1,867
	TOTAL ASSETS	$	10,446		$	9,087		$	208		$	(10,959	)	$	8,782
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	Intercompany accounts payable	$	—		$	615		$	—		$	(615	)	$	—
	All other current liabilities	—			466			9			—			475
	Long-term liabilities	2,832			559			—			—			3,391
	Noncontrolling interest	—			—			—			102			102
	Total partners’ capital	7,614			7,447			199			(10,446		)	4,814
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	10,446		$	9,087		$	208		$	(10,959	)	$	8,782
Condensed Income Statement [Table Text Block]	'
		Three Months Ended June 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,162		$	16		$	—		$	1,178
	Operating costs, expenses, and other	—			1,137			9			(3		)	1,143
	Operating income	—			25			7			3			35
	Income from unconsolidated affiliates	—			48			—			(1		)	47
	Interest expense, net	(71		)	(7		)	—			—			(78		)
	Gain (loss) on debt refinancing, net	1			(1		)	—			—			—
	Equity in consolidated subsidiaries	73			—			—			(73		)	—
	Other income and deductions, net	(8		)	1			—			—			(7		)
	(Loss) income before income taxes	(5		)	66			7			(71		)	(3		)
	Income tax expense	1			—			—			—			1
	Net (loss) income	(6		)	66			7			(71		)	(4		)
	Net income attributable to noncontrolling interest	—			—			—			(4		)	(4		)
	Net (loss) income attributable to Regency Energy Partners LP	$	(6	)	$	66		$	7		$	(75	)	$	(8	)
	Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
	Comprehensive (loss) income	(6		)	66			7			(71		)	(4		)
	Comprehensive income attributable to noncontrolling interest	—			—			—			4			4
	Comprehensive (loss) income attributable to Regency Energy Partners LP	$	(6	)	$	66		$	7		$	(75	)	$	(8	)
		Three Months Ended June 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	635		$	4		$	—		$	639
	Operating costs, expenses, and other	—			602			3			—			605
	Operating income	—			33			1			—			34
	Income from unconsolidated affiliates	—			31			—			—			31
	Interest expense, net	(36		)	(5		)	—			—			(41		)
	Loss on debt refinancing, net	(7		)	—			—			—			(7		)
	Equity in consolidated subsidiaries	62			—			—			(62		)	—
	Other income and deductions, net	(8		)	1			—			—			(7		)
	Income before income taxes	11			60			1			(62		)	10
	Income tax benefit	—			(1		)	—			—			(1		)
	Net income	11			61			1			(62		)	11
	Net income attributable to noncontrolling interest	—			—			—			(1		)	(1		)
	Net income attributable to Regency Energy Partners LP	$	11		$	61		$	1		$	(63	)	$	10
	Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	11			61			1			(62		)	11
	Comprehensive income attributable to noncontrolling interest	—			—			—			1			1
	Comprehensive income attributable to Regency Energy Partners LP	$	11		$	61		$	1		$	(63	)	$	10
		Six Months Ended June 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	2,011		$	31		$	(1	)	$	2,041
	Operating costs, expenses, and other	—			1,972			15			(3		)	1,984
	Operating income	—			39			16			2			57
	Income from unconsolidated affiliates	—			91			—			(1		)	90
	Interest expense, net	(121		)	(13		)	—			—			(134		)
	Gain (loss) on debt refinancing, net	1			(1		)	—			—			—
	Equity in consolidated subsidiaries	137			—			—			(137		)	—
	Other income and deductions, net	(9		)	4			—			—			(5		)
	Income before income taxes	8			120			16			(136		)	8
	Income tax expense (benefit)	1			(2		)	1			—			—
	Net income	7			122			15			(136		)	8
	Net income attributable to noncontrolling interest	—			—			—			(7		)	(7		)
	Net income attributable to Regency Energy Partners LP	$	7		$	122		$	15		$	(143	)	$	1
	Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	7			122			15			(136		)	8
	Comprehensive income attributable to noncontrolling interest	—			—			—			7			7
	Comprehensive income attributable to Regency Energy Partners LP	$	7		$	122		$	15		$	(143	)	$	1
		Six Months Ended June 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,171		$	8		$	—		$	1,179
	Operating costs, expenses, and other	3			1,152			5			—			1,160
	Operating (loss) income	(3		)	19			3			—			19
	Income from unconsolidated affiliates	—			66			—			—			66
Interest expense, net	(69		)	(9		)	—			—			(78		)
Loss on debt refinancing, net	(7		)	—			—			—			(7		)
Equity in consolidated subsidiaries	83			—			—			(83		)	—
Other income and deductions, net	(22		)	1			—			—			(21		)
(Loss) income before income taxes	(18		)	77			3			(83		)	(21		)
Income tax benefit	—			(3		)	—			—			(3		)
Net (loss) income	(18		)	80			3			(83		)	(18		)
Net income attributable to noncontrolling interest	—			—			—			(1		)	(1		)
Net (loss) income attributable to Regency Energy Partners LP	$	(18	)	$	80		$	3		$	(84	)	$	(19	)
Total other comprehensive income (loss)	$	—		$	—		$	—		$	—		$	—
Comprehensive (loss) income	(18		)	80			3			(83		)	(18		)
Comprehensive income attributable to noncontrolling interest	—			—			—			1			1
Comprehensive (loss) attributable to Regency Energy Partners LP	$	(18	)	$	80		$	3		$	(84	)	$	(19	)
Condensed Cash Flow Statement [Table Text Block]	'
		Six Months Ended June 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Cash flows from operating activities	$	—		$	243		$	35		$	(1	)	$	277
	Cash flows from investing activities	—			(657		)	(5		)	(8		)	(670		)
	Cash flows from financing activities	—			429			(6		)	1			424
	Change in cash	—			15			24			(8		)	31
	Cash at beginning of period	—			—			19			—			19
	Cash at end of period	$	—		$	15		$	43		$	(8	)	$	50
		Six Months Ended June 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Cash flows from operating activities	$	—		$	185		$	10		$	—		$	195
	Cash flows from investing activities	—			(882		)	(76		)	—			(958		)
	Cash flows from financing activities	—			697			30			—			727
	Change in cash	—			—			(36		)	—			(36		)
	Cash at beginning of period	—			—			53			—			53
	Cash at end of period	$	—		$	—		$	17		$	—		$	17

Organization_And_Summary_Of_Si3

Organization And Summary Of Significant Accounting Policies Narrative (Details) (USD $)	Apr. 30, 2013	Jun. 30, 2014
In Millions, unless otherwise specified		Aqua - PVR [Member]
Ownership in affiliate	'	51.00%
Business Acquisition, Cost of Acquired Entity, Purchase Price	$1,500	'

Organization_And_Summary_Of_Si4

Organization And Summary Of Significant Accounting Policies Combined Information (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues	$1,178	$639	$2,041	$1,179
Net (loss) income	-4	11	8	-18
Regency [Member]	'	'	'	'
Revenues	'	562	'	911
Net (loss) income	'	20	'	15
SUGS [Member]	'	'	'	'
Revenues	'	77	'	268
Net (loss) income	'	-9	'	-33
Combined [Member]	'	'	'	'
Revenues	'	639	'	1,179
Net (loss) income	'	$11	'	($18)

Partners_Capital_and_Distribut2

Partners' Capital and Distributions Narrative (Details) (USD $)	3 Months Ended		6 Months Ended				1 Months Ended	6 Months Ended	1 Months Ended	6 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jul. 31, 2014	Jun. 30, 2014	Jul. 31, 2014	Jun. 30, 2014	Jul. 31, 2014
					Citi [Member]	Barclays [Member]	ETE And Its Subsidiaries [Member]	Capital Units [Member]	Capital Units [Member]	Capital Units [Member]	Capital Units [Member]
									ETE And Its Subsidiaries [Member]	ETE And Its Subsidiaries [Member]	Eagle Rock [Member]
Equity Distribution Agreement Maximum Aggregate Value Of Common Units Sold	'	'	'	'	$200	$400	'	'	'	'	'
Stock Issued During Period, Shares, Issued for Cash	'	'	'	'	34	31	'	'	'	'	'
Stock Issued During Period, Shares, New Issues	'	'	'	'	'	'	'	'	16,500,000	14,398,848	'
Stock Issued During Period, Value, Acquisitions	'	'	$400	'	'	'	$400	$400	'	'	'
Issuance of common units in connection with acquisitions	6,274,483	6,274,483	6,274,483	6,274,483	'	'	'	'	'	'	8,200,000

Partners_Capital_and_Distribut3

Partners' Capital and Distributions Unit Activity (Details)

3 Months Ended

6 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jul. 31, 2014

Jun. 30, 2014

Common Units [Member]

Common Units [Member]

Class F Units [Member]

Class F Units [Member]

Hoover Energy [Member]

PVR [Member]

ETE And Its Subsidiaries [Member]

ETE And Its Subsidiaries [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Capital Unit [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Limited Partners' Capital Account, Units Outstanding

'

'

'

'

372,077,138

210,850,232

6,274,483

6,274,483

'

'

'

'

Issuance of common units under LTIP, net of forfeitures and tax withholding

'

'

'

'

24,808

'

'

'

'

'

'

'

Issuance of common units under the equity distribution agreements

'

'

'

'

2,374,397

'

'

'

'

'

'

'

Issuance of common units in connection with acquisitions

6,274,483

6,274,483

6,274,483

6,274,483

'

'

'

'

4,040,471

140,388,382

'

'

Issuance of common units to ETE Common Holdings

'

'

'

'

'

'

'

'

'

'

16,500,000

14,398,848

Partners_Capital_and_Distribut4

Partners' Capital and Distributions Quarterly Distributions of Available Cash (Details) (USD $)	3 Months Ended				6 Months Ended
	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Quarterly Distributions of Available Cash [Abstract]	'	'	'	'	'	'
Dividends Payable, Date of Record	7-Aug-14	8-May-14	7-Feb-14	'	'	'
Dividends Payable, Date of Payment	14-Aug-14	15-May-14	14-Feb-14	'	'	'
Distributions per common unit	$0.49	$0.48	$0.48	$0.47	$0.97	$0.93

Loss_Income_Per_Limited_Partne2

(Loss) Income Per Limited Partner Unit Reconciliation of Numerator and Denominator of Basic and Diluted Earnings Per Common Unit (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net (loss) income allocated to limited partners	($18)	$13	($17)	$4
Diluted (loss) income from continuing operations amount	-18	13	-17	4
Weighted average number of common units outstanding	361,071,005	193,065,183	293,931,615	182,070,077
Diluted weighted number of units outstanding	361,071,005	193,421,010	293,931,615	182,392,330
Basic (loss) income per common unit	($0.05)	$0.07	($0.06)	$0.02
Diluted (loss) income per common unit	($0.05)	$0.07	($0.06)	$0.02
Common unit options [Member]	'	'	'	'
Income allocated to dilutive securities	0	0	0	0
Incremental common shares attributable to options	0	24,365	0	19,035
Phantom Units [Member]	'	'	'	'
Income allocated to dilutive securities	$0	$0	$0	$0
Incremental common shares attributable to phantom units	0	331,462	0	303,218

Loss_Income_Per_Limited_Partne3

(Loss) Income Per Limited Partner Unit Antidilutive Securities Excluded from Computations of Earnings Per Unit (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Common unit options [Member]	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	25,165	0	24,188	0
Phantom Units [Member]	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	580,935	0	505,235	0
Series A preferred units [Member]	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,057,662	4,672,835	2,055,949	4,672,835

Acquisitions_Narrative_Details

Acquisitions Narrative (Details) (USD $)

3 Months Ended

6 Months Ended

2 Months Ended

3 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

2 Months Ended

6 Months Ended

1 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Apr. 30, 2013

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Feb. 03, 2014

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Mar. 21, 2014

Jul. 01, 2014

Jul. 31, 2014

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jul. 31, 2014

Jul. 01, 2014

Hoover Energy [Member]

Hoover Energy [Member]

Hoover Energy [Member]

Hoover Energy [Member]

PVR [Member]

PVR [Member]

PVR [Member]

PVR [Member]

Eagle Rock [Member]

ETE And Its Subsidiaries [Member]

Private Common Unit Offering [Member]

Capital Units [Member]

Capital Units [Member]

Capital Units [Member]

Capital Units [Member]

8.375% Senior Notes Due Two Thousand Nineteen [Member]

Hoover Energy [Member]

Hoover Energy [Member]

PVR [Member]

Eagle Rock [Member]

Eagle Rock [Member]

Severance Costs

'

'

'

'

'

'

'

'

'

$10

'

'

'

'

'

'

'

'

'

'

'

Accrued Bonuses

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

Business Acquisition, Transaction Costs

'

'

'

'

'

'

'

'

'

'

'

'

36.1

'

'

'

'

'

'

'

'

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

'

'

'

1,500

'

'

'

293.2

'

'

'

5,700

1,300

'

'

'

'

'

'

'

Partners' Capital Account, Units, Sold in Private Placement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,040,471

'

'

'

'

'

Business Combination, Acquisition Related Costs

'

'

'

'

'

183.6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Retirement Obligation

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

1,178

639

2,041

1,179

'

'

10

15

'

'

314

351

'

'

'

'

'

'

'

'

'

Net (loss) income attributable to Regency Energy Partners LP

-8

10

1

-19

'

'

2

4

'

'

33

35

'

'

'

'

'

'

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

'

'

'

'

$27.82

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities

'

'

'

'

'

'

'

'

'

'

'

'

1,800

499

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.38%

Stock Issued During Period, Value, Acquisitions

'

'

$400

'

'

'

'

'

'

'

'

'

'

'

$400

'

$400

'

'

'

'

Issuance of common units in connection with acquisitions

6,274,483

6,274,483

6,274,483

6,274,483

'

'

'

'

'

'

'

'

'

'

'

'

'

4,040,471

140,388,382

8,200,000

'

Number of Share Received in Exchange of Each Share

'

'

'

'

'

'

'

'

'

'

'

'

1.02

'

'

'

'

'

'

'

'

Acquisitions_PVR_PPA_Table_Det

Acquisitions PVR PPA Table (Details) (PVR [Member], USD $)	Mar. 21, 2014
In Millions, unless otherwise specified
Current assets	$140
Investment in unconsolidated subsidiaries	62
Intangible assets	2,717
Goodwill (1)	353
Other long-term assets	18
Total Assets Acquired	5,993
Current liabilities	161
Long-term debt	1,788
Premium related to senior notes	99
Long-term liabilities	42
Total Liabilities Assumed	2,090
Net Assets Acquired	3,903
Gathering and Transmission Systems [Member]	'
Property, Plant, and Equipment	1,396
Compression Equipment [Member]	'
Property, Plant, and Equipment	342
Gas Plants And Buildings [Member]	'
Property, Plant, and Equipment	110
Coal and timber resources [Member]	'
Property, Plant, and Equipment	454
Other property, plant and equipment [Member]	'
Property, Plant, and Equipment	229
Construction in Progress [Member]	'
Property, Plant, and Equipment	$172

Acquisitions_Hoover_PPA_Detail

Acquisitions Hoover PPA (Details) (Hoover Energy [Member], USD $)	Feb. 03, 2014
In Millions, unless otherwise specified
Accounts receivable, net	$5
Intangible assets	148
Goodwill (1)	30
Total Assets Acquired	298
Accounts payable and accrued liabilities	5
Asset retirement obligation	2
Total Liabilities Assumed	7
Net Assets Acquired	291
Gathering and Transmission Systems [Member]	'
Property, Plant, and Equipment	72
PP&E Compression Equipment [Member]	'
Property, Plant, and Equipment	15
Other property, plant and equipment [Member]	'
Property, Plant, and Equipment	22
Construction in Progress [Member]	'
Property, Plant, and Equipment	$6

Acquisitions_Pro_Forma_Results

Acquisitions Pro Forma Results of Operations Table (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Business Combinations [Abstract]	'	'	'	'
Revenues	$1,178	$923	$2,323	$1,731
Net loss attributable to the Partnership	($18)	($20)	($53)	($78)
Basic net loss per Limited Partner unit	($0.05)	($0.07)	($0.16)	($0.27)
Diluted net loss per Limited Partner unit	($0.05)	($0.07)	($0.16)	($0.27)

Investment_In_Unconsolidated_A2

Investment In Unconsolidated Affiliates Narrative (Details) (USD $)	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Mar. 31, 2014
In Millions, unless otherwise specified		HPC [Member]	MEP {Member]	Lone Star {Member]	Ranch JV {Member]	Aqua - PVR [Member]	Coal Handling [Member]	Grey Ranch JV [Member]
Ownership in affiliate	'	49.99%	50.00%	30.00%	33.33%	51.00%	50.00%	50.00%
Equity Method Investment, Cash Settlement	'	'	'	'	'	'	'	$4
Loss on Sale of Equity Investment	'	'	'	'	'	'	'	-1
Guarantor Obligations, Current Carrying Value	175	'	'	'	'	'	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	$176	'	'	'	'	'	'	'

Investment_In_Unconsolidated_A3

Investment In Unconsolidated Affiliates Carrying Value of Unconsolidated Affiliates (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Equity Method Investments	$2,378	$2,097
HPC [Member]	'	'
Equity Method Investments	434	442
MEP {Member]	'	'
Equity Method Investments	709	548
Lone Star {Member]	'	'
Equity Method Investments	1,135	1,070
Ranch JV {Member]	'	'
Equity Method Investments	39	36
Aqua - PVR [Member]	'	'
Equity Method Investments	50	0
Coal Handling [Member]	'	'
Equity Method Investments	11	0
Grey Ranch JV [Member]	'	'
Equity Method Investments	$0	$1

Investment_In_Unconsolidated_A4

Investment In Unconsolidated Affiliates Changes In Partnership's Investment (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Distributions from unconsolidated affiliates	'	'	$96	$71
Share of earnings of unconsolidated affiliates’ net income (loss)	47	31	90	66
HPC [Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	0	0	0
Distributions from unconsolidated affiliates	-11	-14	-21	-30
Share of earnings of unconsolidated affiliates’ net income (loss)	8	9	16	19
Amortization of excess fair value of investment	-2	-1	-3	-3
MEP {Member]	'	'	'	'
Contributions to unconsolidated affiliates	175	0	175	0
Distributions from unconsolidated affiliates	-19	-18	-37	-38
Share of earnings of unconsolidated affiliates’ net income (loss)	12	10	22	20
Amortization of excess fair value of investment	0	0	0	0
Lone Star {Member]	'	'	'	'
Contributions to unconsolidated affiliates	44	22	71	49
Distributions from unconsolidated affiliates	-32	-23	-57	-40
Share of earnings of unconsolidated affiliates’ net income (loss)	27	13	51	30
Amortization of excess fair value of investment	0	0	0	0
Ranch JV {Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	0	0	1
Distributions from unconsolidated affiliates	-1	0	-1	0
Share of earnings of unconsolidated affiliates’ net income (loss)	3	0	5	0
Amortization of excess fair value of investment	0	0	0	0
Aqua - PVR [Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	'	0	'
Distributions from unconsolidated affiliates	0	'	0	'
Share of earnings of unconsolidated affiliates’ net income (loss)	-1	'	-1	'
Amortization of excess fair value of investment	0	'	0	'
Coal Handling [Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	'	0	'
Distributions from unconsolidated affiliates	0	'	0	'
Share of earnings of unconsolidated affiliates’ net income (loss)	0	'	0	'
Amortization of excess fair value of investment	$0	'	$0	'

Investment_In_Unconsolidated_A5

Investment In Unconsolidated Affiliates Selected I/S Data for each of the Unconsolidated Affiliates (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
HPC [Member]	'	'	'	'
Equity method investments, total revenues	$37	$38	$74	$78
Equity method investments, operating income (loss)	20	19	38	39
Equity method investments, net income (loss)	16	18	31	38
MEP {Member]	'	'	'	'
Equity method investments, total revenues	66	63	132	128
Equity method investments, operating income (loss)	35	33	69	67
Equity method investments, net income (loss)	23	21	44	42
Lone Star {Member]	'	'	'	'
Equity method investments, total revenues	880	425	1,693	783
Equity method investments, operating income (loss)	90	45	174	101
Equity method investments, net income (loss)	89	44	172	99
Ranch JV {Member]	'	'	'	'
Equity method investments, total revenues	11	3	20	6
Equity method investments, operating income (loss)	7	1	14	1
Equity method investments, net income (loss)	8	1	14	1
Aqua - PVR [Member]	'	'	'	'
Equity method investments, total revenues	1	'	1	'
Equity method investments, operating income (loss)	-3	'	-3	'
Equity method investments, net income (loss)	-2	'	-2	'
Coal Handling [Member]	'	'	'	'
Equity method investments, total revenues	3	'	3	'
Equity method investments, operating income (loss)	1	'	1	'
Equity method investments, net income (loss)	$1	'	$1	'

Derivative_Instruments_Narrati

Derivative Instruments Narrative (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Outstanding borrowings in interest rate risk	$850	$510
Maximum	'	'
Credit risk of derivatives	2	'
Reduction in credit risk of derivatives due to netting feature	$1	'

Derivative_Instruments_Schedul

Derivative Instruments Schedule Of Derivative Assets And Liabilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative Asset, Fair Value, Gross Asset	$2	$4
Long-term derivative liabilities	29	19
Long-term derivative liabilities	40	28
Current | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	2	3
Long-term derivative liabilities	11	9
Long Term [Member] | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	0	1
Long-term derivative liabilities	0	0
Long Term [Member] | Derivatives Not Designated as Cash Flow Hedges [Member] | Embedded Derivatives in Series A Preferred Units [Member]	'	'
Long-term derivative liabilities	29	19
Derivative Asset, Noncurrent	$0	$0

Derivative_Instruments_IS_Impa

Derivative Instruments I/S Impact of Derivative Instruments (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

In Millions, unless otherwise specified

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Long Term [Member]

Long Term [Member]

Commodity Derivatives

Commodity Derivatives

Commodity Derivatives

Commodity Derivatives

Embedded Derivatives in Series A Preferred Units [Member]

Embedded Derivatives in Series A Preferred Units [Member]

Embedded Derivatives in Series A Preferred Units [Member]

Embedded Derivatives in Series A Preferred Units [Member]

Not Designated as Hedging Instrument [Member]

Not Designated as Hedging Instrument [Member]

Revenues

Revenues

Revenues

Revenues

Other Income and Deductions, Net

Other Income and Deductions, Net

Other Income and Deductions, Net

Other Income and Deductions, Net

Commodity Derivatives

Commodity Derivatives

Long-term derivative liabilities

$40

$28

'

'

'

'

'

'

'

'

'

'

'

'

$0

$0

Derivative, Gain (Loss) on Derivative, Net

'

'

($14)

$6

($28)

($11)

($5)

$14

($18)

$11

($9)

($8)

($10)

($22)

'

'

LongTerm_Debt_Narrative_Detail

Long-Term Debt Narrative (Details) (USD $)

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Feb. 28, 2014

Jun. 30, 2014

Feb. 28, 2014

Apr. 24, 2014

Mar. 31, 2014

Mar. 25, 2014

Jul. 31, 2014

Jun. 30, 2014

Mar. 31, 2014

Mar. 25, 2014

Apr. 23, 2014

Mar. 31, 2014

Jul. 31, 2014

Jul. 01, 2014

Feb. 28, 2014

Feb. 28, 2014

Jul. 01, 2014

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

8.25% PVR Senior Notes Due Two Thousand Eighteen [Member]

8.25% PVR Senior Notes Due Two Thousand Eighteen [Member]

8.375% PVR Senior Notes Due Two Thousand Twenty [Member]

8.375% PVR Senior Notes Due Two Thousand Twenty [Member]

8.375% PVR Senior Notes Due Two Thousand Twenty [Member]

8.375% PVR Senior Notes Due Two Thousand Twenty [Member]

6.5% PVR Senior Notes Due Two Thousand Twenty One [Member]

6.5% PVR Senior Notes Due Two Thousand Twenty One [Member]

6.5% PVR Senior Notes Due Two Thousand Twenty One [Member]

5.00% Senior Notes Due Two Thousand Twenty Two [Member]

5.00% Senior Notes Due Two Thousand Twenty Two [Member]

Redemption Before December 1, 2021 [Member]

Redemption After December 1, 2021 [Member]

Eagle Rock [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

8.375% Senior Notes Due Two Thousand Nineteen [Member]

Revolving credit facility maximum allowable additional borrowings

$1,500,000,000

'

$1,200,000,000

$1,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Additional Borrowing Capacity

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt weighted-average interest rate

'

'

'

'

2.66%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

900,000,000

'

300,000,000

'

'

473,000,000

473,000,000

'

'

400,000,000

'

700,000,000

'

'

499,000,000

Repayments of Long-term Debt

'

'

'

'

'

'

'

'

'

91,000,000

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

5.88%

'

8.25%

'

'

'

8.38%

'

'

6.50%

'

5.00%

'

'

8.38%

Repayments of Long-term Debt, Principal Portion

'

'

'

'

'

'

'

'

'

83,000,000

'

'

'

'

'

'

'

'

'

'

Senior Note Redeemable Portion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

100.00%

100.00%

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Acquiree's Senior Notes Assumed

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Extinguishment of Debt, Amount

'

'

'

'

'

'

313,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Redemption Price, Percentage

'

'

'

'

'

'

104.13%

'

101.00%

'

'

'

101.00%

'

'

'

'

'

'

'

Debt Instrument Redemption Value

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

Debt Instrument, Increase, Accrued Interest

'

'

'

'

'

'

'

'

'

$8,000,000

'

'

'

'

'

'

'

'

'

'

LongTerm_Debt_Partnerships_Lon

Long-Term Debt Partnership's Long-Term Debt Schedule (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'	'
Senior notes	$4,572	$2,800
Line of Credit Facility, Amount Outstanding	850	510
Unamortized premium and discounts	68	0
Long-term debt	5,490	3,310
Total credit facility limit	1,500	1,200
Availability under revolving loans	-850	-510
Letters of credit	-28	-14
Total available	$622	$676

LongTerm_Debt_LongTerm_Debt_Ma

Long-Term Debt Long-Term Debt Maturities Schedule (Details) (USD $)	Jun. 30, 2014
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'
2014 (remainder)	$0
2015	0
2016	0
2017	0
2018	600
Thereafter	4,822
Total	5,422	[1]
Debt Instrument, Unamortized Premium	82
Debt Instrument, Unamortized Discount	$14
[1]	*Excludes a $82 million unamortized premium on the PVR senior notes assumed by the Partnership and a $14 million unamortized discount on the 2022 Notes.

Commitments_And_Contingencies_2

Commitments And Contingencies Narrative (Details) (USD $)	1 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2014	Jun. 30, 2014
Environmental Remediation Expense	'	$0
Accrual for Environmental Loss Contingencies	'	0
ULS [Member]	'	'
Loss Contingency, Damages Awarded, Value	24	'
Loss Contingency, Damages Sought, Value	'	30
Regency Marcellus [Member]	'	'
Disputed Amount in Litigation	'	17
Loss Contingency, Damages Sought, Value	'	$21

Commitments_And_Contingencies_3

Commitments And Contingencies Environmental Remediation Schedule (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]	'	'
Accrued Environmental Loss Contingencies, Current	$2	$2
Accrued Environmental Loss Contingencies, Noncurrent	8	6
Accrual for Environmental Loss Contingencies	$10	$8

Related_Party_Transactions_Nar

Related Party Transactions Narrative (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Related Party Transaction, NGL Sales	$57	$11	$107	$12
General and administrative	54	18	87	51
ETE	'	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	1	2	3	7
Distribution Made to Limited Partner, Cash Distributions Paid	20	15	37	31
ETE | May Twenty Six Service Agreement	'	'	'	'
Management Fee, Amount Paid	10	'	'	'
ETP [Member]	'	'	'	'
Purchase of compression equipment	22	14	31	25
Lone Star {Member]	'	'	'	'
Related Party Transaction, NGL Sales	'	'	112	'
HPC [Member]	'	'	'	'
General and administrative	$4	$4	$8	$10

Related_Party_Transactions_Rel

Related Party Transactions Related Party Receivables and Payables (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Related party receivables	$19	$28
Related party payables	215	69
ETE And Its Subsidiaries [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	17	25
Related party payables	39	68
HPC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	2	1
Related party payables	1	1
Ranch JV {Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	0	2
MEP {Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party payables	$175	$0

Segment_Information_Narrative_

Segment Information Narrative (Details)	Jun. 30, 2014
HPC [Member]	'
Total general partner interest	49.99%
MEP {Member]	'
Total general partner interest	50.00%
Lone Star {Member]	'
Total general partner interest	30.00%
Ranch JV {Member]	'
Total general partner interest	33.33%
Aqua - PVR [Member]	'
Total general partner interest	51.00%
Coal Handling [Member]	'
Total general partner interest	50.00%

Segment_Information_Operating_

Segment Information Operating Results for Each Segment (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
External Revenues	$1,178	$639	$2,041	$1,179
Intersegment Revenue	0	0	0	0
Segment Margin	350	194	575	347
Operation and maintenance	93	73	171	142
Gathering and Processing	'	'	'	'
External Revenues	1,074	583	1,867	1,069
Intersegment Revenue	0	0	0	0
Segment Margin	269	145	435	248
Operation and maintenance	71	60	132	114
Natural Gas Transportation	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenue	0	0	0	0
Segment Margin	0	0	0	0
Operation and maintenance	0	0	0	0
NGL Services	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenue	0	0	0	0
Segment Margin	0	0	0	0
Operation and maintenance	0	0	0	0
Contract Services	'	'	'	'
External Revenues	78	52	141	101
Intersegment Revenue	4	4	8	7
Segment Margin	63	49	119	97
Operation and maintenance	21	17	41	35
Natural Resources	'	'	'	'
External Revenues	20	0	22	0
Intersegment Revenue	0	0	0	0
Segment Margin	20	0	22	0
Operation and maintenance	5	0	5	0
Corporate	'	'	'	'
External Revenues	6	4	11	9
Intersegment Revenue	0	0	0	0
Segment Margin	2	4	7	9
Operation and maintenance	0	0	1	0
Eliminations	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenue	-4	-4	-8	-7
Segment Margin	-4	-4	-8	-7
Operation and maintenance	($4)	($4)	($8)	($7)

Segment_Information_Reconcilia

Segment Information Reconciliation of Total Segment Margin to Income (Loss) Before Income Taxes (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Information [Abstract]	'	'	'	'
Total segment margin	$350	$194	$575	$347
Operation and maintenance	-93	-73	-171	-142
General and administrative	-54	-18	-87	-51
Gain (loss) on asset sales, net	0	-1	2	-2
Depreciation, depletion and amortization	-168	-68	-262	-133
Income from unconsolidated affiliates	47	31	90	66
Interest expense, net	-78	-41	-134	-78
Loss on debt refinancing, net	0	-7	0	-7
Other income and deductions, net	-7	-7	-5	-21
(LOSS) INCOME BEFORE INCOME TAXES	($3)	$10	$8	($21)

Segment_Information_Total_Segm

Segment Information Total Segment Assets (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Total assets	$15,459	$8,782
Gathering and Processing	'	'
Segment Reporting Information	'	'
Total assets	10,285	4,748
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Total assets	1,144	991
NGL Services	'	'
Segment Reporting Information	'	'
Total assets	1,135	1,070
Contract Services	'	'
Segment Reporting Information	'	'
Total assets	2,007	1,897
Natural Resources	'	'
Segment Reporting Information	'	'
Total assets	514	0
Corporate	'	'
Segment Reporting Information	'	'
Total assets	$374	$76

Segment_Information_Investment

Segment Information Investment in Unconsolidated Affiliates (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Equity Method Investments	$2,378	$2,097
Investment in unconsolidated subsidiaries	2,378	2,097
Gathering and Processing	'	'
Segment Reporting Information	'	'
Equity Method Investments	89	36
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Equity Method Investments	1,143	991
NGL Services	'	'
Segment Reporting Information	'	'
Equity Method Investments	1,135	1,070
Natural Resources	'	'
Segment Reporting Information	'	'
Equity Method Investments	$11	$0

EquityBased_Compensation_Narra

Equity-Based Compensation Narrative (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Equity-Based Compensation [Abstract]	'	'	'	'
Partnership's LTIP units	5,865,584	'	5,865,584	'
Share-based Compensation	$3	$1	$5	$3
Partners' Capital Account, Unit-based Compensation	'	'	5	'
Partnership expects to recognize compensation expense	$30	'	$30	'
Non-vested phantom units period, in years	'	'	'3 years 8 months	'

EquityBased_Compensation_Phant

Equity-Based Compensation Phantom Units Activity (Details) (Phantom Units, USD $)	6 Months Ended
	Jun. 30, 2014
Phantom Units	'
Outstanding at the beginning of the period, Units	982,242
Service condition grants, Units	718,791
Vested service condition, Units	-4,008
Forfeited service condition, Units	-72,185
Outstanding at the end of period, Units	1,624,840
Outstanding at the beginning of the period, Weighted Average Grant Date Fair Value	$23.16
Service condition grants, Weighted Average Grant Date Fair Value	$25.99
Vested service condition, Weighted Average Grant Date Fair Value	$26.53
Forfeited service condition, Weighted Average Grant Date Fair Value	$24.77
Outstanding at the end of the period, Weighted Average Grant Date Fair Value	$24.33

Fair_Value_Measures_Narrative_

Fair Value Measures Narrative (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Measures [Abstract]	'	'
Debt Instrument, Fair Value Disclosure	$4,900	$2,830
Unsecured Long-term Debt, Noncurrent	$4,572	$2,800

Fair_Value_Measures_FV_of_Part

Fair Value Measures FV of Partnership's Derivative Assets And Liabilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Measurement, Assets	$2	$4
Fair Value Measurement, Liabilities	40	28
Derivative Liability, Fair Value, Gross Liability	40	28
Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	2	4
Fair Value Measurement, Liabilities	11	9
Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	29	19
Natural Gas Transportation	'	'
Fair Value Measurement, Assets	1	2
Fair Value Measurement, Liabilities	5	4
Natural Gas Transportation | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	1	2
Fair Value Measurement, Liabilities	5	4
Natural Gas Transportation | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
NGLs	'	'
Fair Value Measurement, Assets	1	2
Fair Value Measurement, Liabilities	2	4
NGLs | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	1	2
Fair Value Measurement, Liabilities	2	4
NGLs | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
Condensate	'	'
Fair Value Measurement, Liabilities	4	1
Condensate | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Liabilities	4	1
Condensate | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Liabilities	0	0
Embedded Derivatives in Series A Preferred Units [Member]	'	'
Embedded Derivatives in Series A Preferred Units	29	19
Embedded Derivatives in Series A Preferred Units [Member] | Significant Observable Inputs (Level 2)	'	'
Embedded Derivatives in Series A Preferred Units	0	0
Embedded Derivatives in Series A Preferred Units [Member] | Unobservable Inputs (Level 3)	'	'
Embedded Derivatives in Series A Preferred Units	$29	$19

Fair_Value_Measures_Significan

Fair Value Measures Significant Unobservable Inputs for FV Estimation of Embedded Derivatives (Details)	Jun. 30, 2014
Fair Value Measures [Abstract]	'
Fair Value, Embedded Derivatives Significant Unobservable Input, Credit Spread	3.91%
Fair Value, Embedded Derivatives Significant Unobservable Input, Volatility	21.40%

Fair_Value_Measures_Valuation_

Fair Value Measures Valuation Changes in Level 3 Derivatives (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Fair Value Measures [Abstract]	'
Beginning balance	$19
Change in fair value	10
Ending balance	$29

Consolidating_Guarantor_Financ2

Consolidating Guarantor Financial Information Condensed Balance Sheet (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	$50	$19	$17	$53
Intercompany accounts receivable	0	0	'	'
All other current assets	542	381	'	'
Property, plant, and equipment, net	7,416	4,418	'	'
Investment in subsidiaries	0	0	'	'
Investment in unconsolidated subsidiaries	2,378	2,097	'	'
All other assets	5,073	1,867	'	'
TOTAL ASSETS	15,459	8,782	'	'
Intercompany accounts payable	0	0	'	'
All other current liabilities	730	475	'	'
Long-term liabilities	5,610	3,391	'	'
Noncontrolling interest	107	102	'	'
Total partners’ capital	9,012	4,814	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	15,459	8,782	'	'
Parent Company [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	0	0	0	0
Intercompany accounts receivable	0	0	'	'
All other current assets	0	0	'	'
Property, plant, and equipment, net	0	0	'	'
Investment in subsidiaries	18,368	10,446	'	'
Investment in unconsolidated subsidiaries	0	0	'	'
All other assets	0	0	'	'
TOTAL ASSETS	18,368	10,446	'	'
Intercompany accounts payable	0	0	'	'
All other current liabilities	0	0	'	'
Long-term liabilities	4,673	2,832	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	13,695	7,614	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	18,368	10,446	'	'
Consolidation, Eliminations [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	-8	0	0	0
Intercompany accounts receivable	0	-615	'	'
All other current assets	-1	0	'	'
Property, plant, and equipment, net	-89	0	'	'
Investment in subsidiaries	-18,368	-10,446	'	'
Investment in unconsolidated subsidiaries	157	102	'	'
All other assets	0	0	'	'
TOTAL ASSETS	-18,309	-10,959	'	'
Intercompany accounts payable	0	-615	'	'
All other current liabilities	0	0	'	'
Long-term liabilities	-3	0	'	'
Noncontrolling interest	107	102	'	'
Total partners’ capital	-18,413	-10,446	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	-18,309	-10,959	'	'
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	43	19	17	53
Intercompany accounts receivable	0	0	'	'
All other current assets	5	15	'	'
Property, plant, and equipment, net	269	174	'	'
Investment in subsidiaries	0	0	'	'
Investment in unconsolidated subsidiaries	0	0	'	'
All other assets	0	0	'	'
TOTAL ASSETS	317	208	'	'
Intercompany accounts payable	0	0	'	'
All other current liabilities	8	9	'	'
Long-term liabilities	3	0	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	306	199	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	317	208	'	'
Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	15	0	0	0
Intercompany accounts receivable	0	615	'	'
All other current assets	538	366	'	'
Property, plant, and equipment, net	7,236	4,244	'	'
Investment in subsidiaries	0	0	'	'
Investment in unconsolidated subsidiaries	2,221	1,995	'	'
All other assets	5,073	1,867	'	'
TOTAL ASSETS	15,083	9,087	'	'
Intercompany accounts payable	0	615	'	'
All other current liabilities	722	466	'	'
Long-term liabilities	937	559	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	13,424	7,447	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$15,083	$9,087	'	'

Consolidating_Guarantor_Financ3

Consolidating Guarantor Financial Information Condensed Income Statement (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues	$1,178	$639	$2,041	$1,179
Operating costs, expenses, and other	1,143	605	1,984	1,160
Operating income (loss)	35	34	57	19
Income from unconsolidated affiliates	47	31	90	66
Interest expense, net	-78	-41	-134	-78
Gain (loss) on debt refinancing, net	0	-7	0	-7
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	-7	-7	-5	-21
(Loss) income before income taxes	-3	10	8	-21
Income tax expense (benefit)	1	-1	0	-3
Net (loss) income	-4	11	8	-18
Net income attributable to noncontrolling interest	-4	-1	-7	-1
Net (loss) income attributable to Regency Energy Partners LP	-8	10	1	-19
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	-4	11	8	-18
Comprehensive income attributable to noncontrolling interest	4	1	7	1
Comprehensive (loss) income attributable to Regency Energy Partners LP	-8	10	1	-19
Parent Company [Member]	'	'	'	'
Revenues	0	0	0	0
Operating costs, expenses, and other	0	0	0	3
Operating income (loss)	0	0	0	-3
Income from unconsolidated affiliates	0	0	0	0
Interest expense, net	-71	-36	-121	-69
Gain (loss) on debt refinancing, net	1	-7	1	-7
Equity in consolidated subsidiaries	73	62	137	83
Other income and deductions, net	-8	-8	-9	-22
(Loss) income before income taxes	-5	11	8	-18
Income tax expense (benefit)	1	0	1	0
Net (loss) income	-6	11	7	-18
Net income attributable to noncontrolling interest	0	0	0	0
Net (loss) income attributable to Regency Energy Partners LP	-6	11	7	-18
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	-6	11	7	-18
Comprehensive income attributable to noncontrolling interest	0	0	0	0
Comprehensive (loss) income attributable to Regency Energy Partners LP	-6	11	7	-18
Guarantor Subsidiaries [Member]	'	'	'	'
Revenues	1,162	635	2,011	1,171
Operating costs, expenses, and other	1,137	602	1,972	1,152
Operating income (loss)	25	33	39	19
Income from unconsolidated affiliates	48	31	91	66
Interest expense, net	-7	-5	-13	-9
Gain (loss) on debt refinancing, net	-1	0	-1	0
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	1	1	4	1
(Loss) income before income taxes	66	60	120	77
Income tax expense (benefit)	0	-1	-2	-3
Net (loss) income	66	61	122	80
Net income attributable to noncontrolling interest	0	0	0	0
Net (loss) income attributable to Regency Energy Partners LP	66	61	122	80
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	66	61	122	80
Comprehensive income attributable to noncontrolling interest	0	0	0	0
Comprehensive (loss) income attributable to Regency Energy Partners LP	66	61	122	80
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Revenues	16	4	31	8
Operating costs, expenses, and other	9	3	15	5
Operating income (loss)	7	1	16	3
Income from unconsolidated affiliates	0	0	0	0
Interest expense, net	0	0	0	0
Gain (loss) on debt refinancing, net	0	0	0	0
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	0	0	0	0
(Loss) income before income taxes	7	1	16	3
Income tax expense (benefit)	0	0	1	0
Net (loss) income	7	1	15	3
Net income attributable to noncontrolling interest	0	0	0	0
Net (loss) income attributable to Regency Energy Partners LP	7	1	15	3
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	7	1	15	3
Comprehensive income attributable to noncontrolling interest	0	0	0	0
Comprehensive (loss) income attributable to Regency Energy Partners LP	7	1	15	3
Consolidation, Eliminations [Member]	'	'	'	'
Revenues	0	0	-1	0
Operating costs, expenses, and other	-3	0	-3	0
Operating income (loss)	3	0	2	0
Income from unconsolidated affiliates	-1	0	-1	0
Interest expense, net	0	0	0	0
Gain (loss) on debt refinancing, net	0	0	0	0
Equity in consolidated subsidiaries	-73	-62	-137	-83
Other income and deductions, net	0	0	0	0
(Loss) income before income taxes	-71	-62	-136	-83
Income tax expense (benefit)	0	0	0	0
Net (loss) income	-71	-62	-136	-83
Net income attributable to noncontrolling interest	-4	-1	-7	-1
Net (loss) income attributable to Regency Energy Partners LP	-75	-63	-143	-84
Total other comprehensive income (loss)	0	0	0	0
Comprehensive (loss) income	-71	-62	-136	-83
Comprehensive income attributable to noncontrolling interest	4	1	7	1
Comprehensive (loss) income attributable to Regency Energy Partners LP	($75)	($63)	($143)	($84)

Consolidating_Guarantor_Financ4

Consolidating Guarantor Financial Information Condensed Cash Flow Statement (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Condensed Financial Statements, Captions [Line Items]	'	'
Net Cash Provided by (Used in) Operating Activities	$277	$195
Net Cash Provided by (Used in) Investing Activities	-670	-958
Net Cash Provided by (Used in) Financing Activities	424	727
Cash and Cash Equivalents, Period Increase (Decrease)	31	-36
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	50	17
Parent Company [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Net Cash Provided by (Used in) Operating Activities	0	0
Net Cash Provided by (Used in) Investing Activities	0	0
Net Cash Provided by (Used in) Financing Activities	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	0	0
Guarantor Subsidiaries [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Net Cash Provided by (Used in) Operating Activities	243	185
Net Cash Provided by (Used in) Investing Activities	-657	-882
Net Cash Provided by (Used in) Financing Activities	429	697
Cash and Cash Equivalents, Period Increase (Decrease)	15	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	15	0
Non-Guarantor Subsidiaries [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Net Cash Provided by (Used in) Operating Activities	35	10
Net Cash Provided by (Used in) Investing Activities	-5	-76
Net Cash Provided by (Used in) Financing Activities	-6	30
Cash and Cash Equivalents, Period Increase (Decrease)	24	-36
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	43	17
Consolidation, Eliminations [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Net Cash Provided by (Used in) Operating Activities	-1	0
Net Cash Provided by (Used in) Investing Activities	-8	0
Net Cash Provided by (Used in) Financing Activities	1	0
Cash and Cash Equivalents, Period Increase (Decrease)	-8	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	($8)	$0