Resources Connection 10-Q 6 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	9 Months Ended
	Sep. 30, 2014	Oct. 31, 2014
Entity Information	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'
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	'	403,726,597

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$15	$19
Trade accounts receivable, net	542	292
Related party receivables	52	28
Inventories	71	42
Other current assets	36	19
Total current assets	716	400
Property, plant and equipment	9,915	5,050
Less accumulated depreciation and depletion	-922	-632
Property, plant and equipment, net	8,993	4,418
Investments in unconsolidated affiliates	2,371	2,097
Other, net of accumulated amortization of debt issuance costs of $30 and $24	100	57
Intangible assets, net of accumulated amortization of $179 and $107	3,472	682
Goodwill	1,528	1,128
TOTAL ASSETS	17,180	8,782
Current Liabilities:	'	'
Drafts payable	23	26
Trade accounts payable	559	291
Related party payables	44	69
Accrued interest	97	38
Other current liabilities	102	51
Total current liabilities	825	475
Long-term derivative liabilities	31	19
Other long-term liabilities	74	30
Long-term debt, net	6,427	3,310
Commitments and contingencies	'	'
Series A Preferred Units, redemption amounts of $38 and $38	32	32
Partners’ capital and noncontrolling interest:	'	'
Common units	8,741	3,886
Class F units	151	146
General partner interest	782	782
Total partners’ capital	9,674	4,814
Noncontrolling interest	117	102
Total partners’ capital and noncontrolling interest	9,791	4,916
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$17,180	$8,782

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets Balance Sheet (Paranthetical) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Paranthetical [Abstract]	'	'
Other, accumulated amortization of debt issuance costs	$30	$24
Intangible assets, net of accumulated amortization	179	107
Series A preferred units, redemption amount	$38	$38

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
REVENUES	'	'	'	'
Gas sales, including related party amounts of $23, $22, $58 and $56	$549	$213	$1,359	$600
NGL sales, including related party amounts of $89, $11, $196 and $23	555	286	1,308	766
Gathering, transportation and other fees, including related party amounts of $13, $6, $26 and $20	283	147	682	405
Net realized and unrealized gain (loss) from derivatives	18	-10	0	0
Other	78	29	175	73
Total revenues	1,483	665	3,524	1,844
OPERATING COSTS AND EXPENSES	'	'	'	'
Cost of sales, including related party amounts of $19, $8, $45 and $35	1,051	477	2,517	1,309
Operation and maintenance	129	78	300	220
General and administrative	36	13	123	64
Loss (gain) on asset sales, net	1	-1	-1	1
Depreciation, depletion and amortization	122	74	384	207
Total operating costs and expenses	1,339	641	3,323	1,801
OPERATING INCOME	144	24	201	43
Income from unconsolidated affiliates	53	37	143	103
Interest expense, net	-86	-41	-220	-119
Gain (loss) on debt refinancing, net	2	0	2	-7
Other income and deductions, net	-2	24	-7	3
INCOME BEFORE INCOME TAXES	111	44	119	23
Income tax expense (benefit)	4	2	4	-1
NET INCOME	107	42	115	24
Net income attributable to noncontrolling interest	-4	-3	-11	-4
NET INCOME ATTRIBUTABLE TO REGENCY ENERGY PARTNERS LP	103	39	104	20
Amounts attributable to Series A Preferred Units	1	1	3	5
General partner’s interest, including IDRs	10	3	22	8
Beneficial conversion feature for Class F units	1	2	5	3
Pre-acquisition loss from SUGS allocated to predecessor equity	0	0	0	-36
Limited partners’ interest in net income	91	33	74	40
Basic and diluted net income per common unit:	'	'	'	'
Weighted average number of common units outstanding	397,961,321	209,559,854	328,989,245	191,334,032
Basic income per common unit	$0.23	$0.16	$0.22	$0.21
Diluted income per common unit	$0.23	$0.05	$0.22	$0.21
Distributions per common unit	$0.50	$0.47	$1.47	$1.40
Amount allocated to Class F units due to beneficial conversion feature	$1	$2	$5	$3
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	$0.27	$0.81	$0.45

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Operations Statements of Operations (Paranthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Paranthetical [Abstract]	'	'	'	'
Gas sales, related party amounts	$23	$22	$58	$56
NGL sales, related party amounts	89	11	196	23
Gathering, transportation and other fees, related party amounts	13	6	26	20
Cost of sales, related party amounts	$19	$8	$45	$35

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Net income	$107	$42	$115	$24
Total other comprehensive income	0	0	0	0
Comprehensive income	107	42	115	24
Comprehensive income attributable to noncontrolling interest	4	3	11	4
Comprehensive income attributable to Regency Energy Partners LP	$103	$39	$104	$20

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements Of Cash Flows (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
OPERATING ACTIVITIES:	'	'
Net income	$115	$24
Reconciliation of net income to net cash flows provided by operating activities:	'	'
Depreciation, depletion and amortization, including debt issuance cost amortization and bond premium write-off and amortization	363	211
Income from unconsolidated affiliates	-143	-103
Derivative valuation changes	-3	3
Loss (gain) on asset sales, net	-1	1
Unit-based compensation expenses	8	5
Cash flow changes in current assets and liabilities:	'	'
Trade accounts receivable and related party receivables	-45	-73
Other current assets and other current liabilities	52	-26
Trade accounts payable and related party payables	73	103
Distributions of earnings received from unconsolidated affiliates	147	108
Cash flow changes in other assets and liabilities	4	128
Net cash flows provided by operating activities	570	381
INVESTING ACTIVITIES:	'	'
Capital expenditures	-764	-762
Capital contributions to unconsolidated affiliates	-274	-125
Distributions in excess of earnings of unconsolidated affiliates	47	232
Acquisitions, net of cash received	-790	-463
Proceeds from asset sales	7	13
Net cash flows used in investing activities	-1,774	-1,105
FINANCING ACTIVITIES:	'	'
Repayments under revolving credit facility, net	-436	-15
Proceeds from issuances of senior notes	1,600	1,000
Redemptions of senior notes	-403	-163
Debt issuance costs	-29	-24
Drafts payable	-3	8
Partner distributions and distributions on unvested unit awards	-492	-282
Common unit offering, net of issuance costs	800	0
Common units issued under equity distribution program, net of costs	162	149
Distributions to Series A Preferred Units	-3	-5
Noncontrolling interest contributions, net of distributions	4	15
Net cash flows provided by financing activities	1,200	683
Net change in cash and cash equivalents	-4	-41
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	15	12
Supplemental cash flow information:	'	'
Accrued capital expenditures	61	70
Issuance of Class F and common units in connection with SUGS Acquisition	0	961
Interest paid, net of amounts capitalized	196	0
Issuance of common units in connection with PVR, Hoover and Eagle Rock acquisitions	4,281	0
Long-term debt assumed in PVR Acquisition	1,887	0
Long-term debt exchanged in connection with the Eagle Rock Midstream Acquisition	$499	$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	162	162	0	0	0
Issuance of common units to ETE Common Holdings	800	800	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
Issuance of common units in connection with Eagle Rock Acquisition	266	266	0	0	0
Unit-based compensation expenses	8	8	0	0	0
Partner distributions and distributions on unvested unit awards	-492	-470	0	-22	0
Noncontrolling interest contributions, net of distributions	4	0	0	0	4
Net income	115	77	5	22	11
Distributions to Series A Preferred Units	-3	-3	0	0	0
Balance at Sep. 30, 2014	$9,791	$8,741	$151	$782	$117

Organization_And_Summary_Of_Si

Organization And Summary Of Significant Accounting Policies (Notes)	9 Months Ended
	Sep. 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; natural gas and NGL marketing and trading, 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:
		Nine Months Ended September 30, 2013 (1)
	Revenues:
	Partnership	$	1,576
	SUGS	268
	Combined	$	1,844
	Net income (loss):
	Partnership	$	60
	SUGS	(36		)
	Combined	$	24
	(1) The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include four months of activity for the nine months ended September 30, 2013.
	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)	9 Months Ended
	Sep. 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 nine months ended September 30, 2014, the Partnership received net proceeds of $34 million from common units sold pursuant to this equity distribution agreement. 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 nine months ended September 30, 2014, the Partnership received net proceeds of $128 million from common units sold pursuant to this equity distribution agreement; $272 million remains available to be issued as of September 30, 2014.
	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. Proceeds from the issuance were used to fund a portion of the cash consideration paid to Eagle Rock in connection with the Eagle Rock Midstream Acquisition.
	Units Activity. The change in common and Class F units during the nine months ended September 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	37,191		—
	Issuance of common units under the equity distribution agreements	5,442,878		—
	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	30,890,565		—
	Issuance of common units in connection with Eagle Rock Midstream Acquisition	8,245,859		—
	Balance - September 30, 2014	399,895,578		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
	September 30, 2014		November 7, 2014	November 14, 2014	$0.50

Income_Per_Limited_Partner_Uni

Income Per Limited Partner Unit (Notes)	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Income Per Limited Partner Unit	'
	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 nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,
		2014							2013
		Income			Units		Per-Unit		Income			Units	Per-Unit
		(Numerator)			(Denominator)		Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amount allocated to common units	$	91		397,961,321		$	0.23	$	33		209,559,854	$	0.16
	Effect of Dilutive Securities:
	Common unit options	—			31,777				—			32,489
	Phantom units	—			737,205				—			435,606
	Series A Preferred Units	—			—				(23		)	2,047,571
	Diluted income per unit	$	91		398,730,303		$	0.23	$	10		212,075,520	$	0.05
		Nine Months Ended September 30,
		2014							2013
		Income			Units		Per-Unit		Income			Units	Per-Unit
		(Numerator)			(Denominator)		Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amount allocated to common units	$	74		328,989,245		$	0.22	$	40		191,334,032	$	0.21
	Effect of Dilutive Securities:
	Common unit options	—			27,574				—			23,931
	Phantom units	—			590,034				—			351,811
	Diluted income per unit	$	74		329,606,853		$	0.22	$	40		191,709,774	$	0.21
	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 September 30, 2014		Nine Months Ended September 30, 2014		Nine Months Ended September 30, 2013
	Series A Preferred Units	2,061,191		2,057,716		2,047,571

Acquisitions_Notes

Acquisitions (Notes)	9 Months Ended
	Sep. 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 Partnership’s revolving credit facility. The Partnership is accounting 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. This acquisition is expected to complement the Partnership’s core gathering and processing business and is expected to further diversify the Partnership’s geographic presence in the mid-continent region, east Texas and south Texas. Revenues attributable to Eagle Rock’s operations included in the statement of operations for the three and nine months ended September 30, 2014 was $472 million. Net income attributable to Eagle Rock’s operations included in the statement of operations for the three and nine months ended September 30, 2014 was $18 million.
	Management’s evaluation of the assigned fair values is ongoing. The table below represents a preliminary allocation of the total purchase price:
	Assets	At July 1, 2014
	Current assets	$	115
	Property, plant and equipment	1,329
	Other long-term assets	4
	Total Assets Acquired	$	1,448
	Liabilities
	Current liabilities	$	109
	Long-term debt	499
	Long-term liabilities	12
	Total Liabilities Assumed	$	620
	Net Assets Acquired	$	828
	The fair values of the assets acquired and liabilities assumed is being determined using various valuation techniques, including the income and market approaches.
	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 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 nine months ended September 30, 2014 were $302 million and $653 million, respectively. Net income attributable to PVR’s operations included in the statement of operations for the three and nine months ended September 30, 2014 were $84 million and $119 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 March 21, 2014
	Current assets	$	149
	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	185
	Investments in unconsolidated affiliates	62
	Intangible assets	2,717
	Goodwill (1)	370
	Other long-term assets	18
	Total Assets Acquired	$	6,032
	Liabilities
	Current liabilities	$	168
	Long-term debt	1,788
	Premium related to senior notes	99
	Long-term liabilities	30
	Total Liabilities Assumed	$	2,085
	Net Assets Acquired	$	3,947
	(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 affiliates 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. The Partnership recorded $10 million of severance payments due to the change in control and recorded $2 million in retention bonuses that were paid 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 million, consisting of (i) 4,040,471 common units issued to Hoover and (ii) $184 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 nine months ended September 30, 2014 were $11 million and $26 million, respectively. Net income attributable to Hoover’s operations included in the statement of operations for the three and nine months ended September 30, 2014 were losses of $2 million and income of $2 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	60
	Compression equipment	16
	Gas plants and buildings	12
	Other property, plant, and equipment	23
	Construction in process	6
	Intangible assets	148
	Goodwill (1)	30
	Total Assets Acquired	$	300
	Liabilities
	Accounts payable and accrued liabilities	$	5
	Asset retirement obligation	2
	Total Liabilities Assumed	$	7
	Net Assets Acquired	$	293
	(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 nine months ended September 30, 2014 and 2013 are presented as if the PVR, Hoover and Eagle Rock Midstream 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. Actual results for the three months ended September 30, 2014 include PVR, Hoover and the Eagle Rock midstream business for the entire period.
	Three Months Ended September 30,					Nine Months Ended September 30,
	2014		2013			2014			2013
Revenues	$	1,483	$	1,230		$	4,354		$	3,453
Net income (loss) attributable to the Partnership	103		(6		)	(23		)	(119		)
Basic net income (loss) per Limited Partner unit	$	0.23	$	(0.01	)	$	(0.23	)	$	(0.01	)
Diluted net income (loss) per Limited Partner unit	$	0.23	$	(0.01	)	$	(0.23	)	$	(0.01	)

Investment_In_Unconsolidated_A

Investment In Unconsolidated Affiliates (Notes)	9 Months Ended
	Sep. 30, 2014
Investment In Unconsolidated Subsidiaries [Abstract]	'
Investment In Unconsolidated Affiliates	'
	INVESTMENTS IN UNCONSOLIDATED AFFILIATES
	As of September 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, a 50% membership interest in Coal Handling, and a 50% partnership interest in Sweeny JV. The Partnership’s interests in the Aqua - PVR and Coal Handling joint ventures were acquired in the PVR Acquisition and its interest in Sweeny JV was acquired in the Eagle Rock Midstream Acquisition. In March 2014, the Partnership entered into an 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.
	The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of September 30, 2014 and December 31, 2013 is as follows:
		September 30, 2014			December 31, 2013
	HPC	$	428		$	442
	MEP	703			548
	Lone Star	1,145			1,070
	Ranch JV	35			36
	Aqua - PVR	47			—
	Coal Handling	12			—
	Sweeny JV	1			—
	Grey Ranch	—			1
	Total	$	2,371		$	2,097
	The following tables summarize the Partnership’s investment activities in each of the unconsolidated affiliates for the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	—		$	15		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(14		)	(17		)	(37		)	(7		)	(1		)	(2		)
	Share of earnings of unconsolidated affiliates’ net income (loss)	9			11			31			3			(1		)	1
	Amortization of excess fair value of investment	(1		)	—			—			—			—			—
		Three Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	51		$	1
	Distributions from unconsolidated affiliates	(196		)	(18		)	(16		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	9			11			18			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Nine Months Ended September 30, 2014
		HPC			MEP (2)			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	86		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(35		)	(54		)	(94		)	(8		)	(1		)	(2		)
	Share of earnings of unconsolidated affiliates’ net income (loss)	25			33			83			7			(2		)	1
	Amortization of excess fair value of investment	(4		)	—			—			—			—			—
		Nine Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	100		$	2
	Distributions from unconsolidated affiliates	(226		)	(56		)	(56		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	28			31			48			—
	Amortization of excess fair value of investment	(4		)	—			—			—
	(1) The Partnership received a non-recurring return of capital of $185 million from HPC in September 2013.
	(2) The Partnership paid $175 million to MEP in September 2014.
	The following tables present selected income statement data for each of the unconsolidated affiliates, on a 100% basis, for the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	39		$	64		$	1,166		$	10		$	2		$	3
	Operating income (loss)	21			33			105			8			(1		)	1
	Net income (loss)	19			21			104			8			(1		)	1
		Three Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	66		$	537		$	4
	Operating income	19			34			61			1
	Net income	18			21			61			1
		Nine Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	113		$	196		$	2,859		$	30		$	2		$	6
	Operating income (loss)	59			102			279			22			(4		)	3
	Net income (loss)	50			65			276			21			(4		)	3
		Nine Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	116		$	194		$	1,320		$	10
	Operating income	58			101			162			2
	Net income	56			63			160			2

Derivative_Instruments_Notes

Derivative Instruments (Notes)	9 Months Ended
	Sep. 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.
	Commodity Derivative Instruments - Marketing & Trading. The Partnership conducts natural gas marketing and trading activities intended to capitalize on favorable price differentials between various receipt and delivery locations.
	As part of its natural gas marketing and trading activities, the Partnership enters into both financial derivatives and physical contracts. These financial derivatives, primarily basis swaps, are transacted: (i) to economically hedge subscribed capacity exposed to market rate fluctuations and (ii) to mitigate the price risk related to other purchase and sales of natural gas. By entering into a basis swap, one pricing index is exchanged for another, effectively locking in the margin between the natural gas purchase and sale by removing index spread risk on the combined physical and financial transaction. Changes in the fair value of these financial and physical contracts are recorded as adjustments to natural gas sales and realized (unrealized) gain (loss) from derivatives, as appropriate.
	The Partnership has credit exposure to additional counterparties. The Partnership monitors its exposure to any single counterparty and the creditworthiness of its counterparties on an ongoing basis. In addition, the Partnership's natural gas purchase and sale contracts, for certain counterparties, are subject to counterparty netting agreements governing settlement under such natural gas purchase and sales contracts, and when possible, the Partnership nets the open positions of each counterparty.
	Interest Rate Risk. The Partnership is exposed to variable interest rate risk as a result of borrowings under its revolving credit facility. As of September 30, 2014, the Partnership had $689 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 September 30, 2014 would be $10 million, which would be reduced by $2 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 September 30, 2014 and December 31, 2013 are detailed below:
		Assets						Liabilities
		September 30, 2014			December 31, 2013			September 30, 2014		December 31, 2013
	Derivatives not designated as cash flow hedges
	Current amounts
	Commodity contracts	$	11		$	3		$	3	$	9
	Long-term amounts
	Commodity contracts	1			1			1		—
	Embedded derivatives in Series A Preferred Units	—			—			30		19
	Total derivatives	$	12		$	4		$	34	$	28
	The Partnership’s statements of operations for the three and nine months ended September 30, 2014 and 2013 were impacted by derivative instruments activities as follows:
				Three Months Ended September 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		$	(10	)
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(1		)	24
				$	17		$	14
				Nine Months Ended September 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
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(11		)	2
				$	(11	)	$	2

LongTerm_Debt_Notes

Long-Term Debt (Notes)	9 Months Ended
	Sep. 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:
		September 30, 2014			December 31, 2013
	Senior notes	$	5,688		$	2,800
	Revolving loans	689			510
	Unamortized premium and discounts	50			—
	Long-term debt	$	6,427		$	3,310
	Availability under revolving credit facility:
	Total credit facility limit	$	1,500		$	1,200
	Revolving loans	(689		)	(510		)
	Letters of credit	(25		)	(14		)
	Total available	$	786		$	676
	Long-term debt maturities as of September 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		5,777
	Total *		$	6,377
	*	Excludes a $70 million unamortized premium on the 2020 PVR Notes and the 2021 PVR Notes assumed by the Partnership and a $20 million unamortized discount on the combined 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 allowed the Partnership to assume the series of PVR senior notes that mature prior to the Credit Agreement.
	In September 2014, RGS entered into the Second Amendment to the Credit Agreement to, among other things, increase the letter of credit sublimit from $50 million to $100 million, with none of the four individual issuing banks being required to issue letters of credit in excess of $25 million; increase in the general basket of permitted investments from $300 million to $500 million; add provisions permitting investments in ORS affording it similar treatment to the Partnership’s existing joint ventures; and update various swap agreement provisions to conform to current market standards.
	The weighted average interest rate on the amounts outstanding under the Partnership’s Credit Agreement was 2.66% as of September 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, ELG and ORS. 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 issued by the Partnership and Finance Corp. (the “New Partnership Notes”). The New Partnership Notes 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 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 will be guaranteed by substantially all of the Partnership’s consolidated subsidiaries, except Finance Corp., ELG and ORS. The October 2022 Notes 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.
	On October 28, 2014, the Partnership issued a notice of redemption to the holders of the $600 million 2018 Notes, with a redemption date of December 2, 2014, for a total price of 103.438%.
	At September 30, 2014, the Partnership was in compliance with all material covenants under the Credit Agreement and the indentures governing the Senior Notes.
	The Senior Notes issued by the Partnership and Finance Corp. will be fully and unconditionally guaranteed, on a joint and several basis, by substantially all of the Partnership’s existing, 100% owned, consolidated subsidiaries, except for ELG, Aqua - PVR and ORS.

Commitments_And_Contingencies_

Commitments And Contingencies (Notes)	9 Months Ended
	Sep. 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, (vi) 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 did 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 September 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.
		September 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 nine months ended September 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.
	PADEP Consent Assessment. On October 21, 2013 the PADEP presented the Partnership’s subsidiary, Regency Marcellus Gas Gathering LLC (“Regency Marcellus”), with a proposed Consent Assessment of Civil Penalty totaling approximately $0.3 million in connection with alleged erosion and sediment control violations incurred during construction of its pipelines and related facilities in Lycoming and Tioga Counties, Pennsylvania. In September 2014, Regency Marcellus entered into a Consent Assessment of Civil Penalty (“Assessment”) with the PADEP, settling and resolving the penalty assessment. Pursuant to the Assessment, Regency Marcellus agreed to pay a civil penalty of approximately $0.3 million to settle the aforementioned violations alleged by the PADEP. Such penalty was paid in full in September 2014.
	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)	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	As of September 30, 2014 and December 31, 2013, details of the Partnership’s related party receivables and related party payables were as follows:
		September 30, 2014		December 31, 2013
	Related party receivables
	ETE and its subsidiaries	$	48	$	25
	HPC	1		1
	Ranch JV	—		2
	Other	3		—
	Total related party receivables	$	52	$	28
	Related party payables
	ETE and its subsidiaries	$	43	$	68
	HPC	1		1
	Total related party payables	$	44	$	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 September 30, 2014 and 2013, respectively, and $4 million and $9 million for the nine months ended September 30, 2014 and 2013, respectively.
	In conjunction with distributions by the Partnership to the limited and general partner interests, ETE and its subsidiaries received cash distributions of $53 million and $31 million for the three months ended September 30, 2014 and 2013, respectively, and $119 million and $62 million for the nine months ended September 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 $27 million and $39 million during the three months ended September 30, 2014 and 2013, respectively, and $58 million and $76 million for the nine months ended September 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 three and nine months ended September 30, 2014, the Partnership had recorded $86 million and $193 million, respectively, 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 $3 million and $4 million for the three months ended September 30, 2014 and 2013, respectively, and $11 million and $14 million for the nine months ended September 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)	9 Months Ended
	Sep. 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, the gathering and disposing of salt water, and natural gas and NGL marketing and trading. This segment also includes the Partnership’s 60% membership interest in 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, the Partnership’s 50% interest in Sweeny JV, the Partnership’s 51% membership interest in Aqua - PVR, which transports and supplies fresh water to natural gas producers in the Marcellus shale in Pennsylvania, and the Partnership’s 75% membership interest in ORS, which will operate a natural gas gathering system in the Utica shale in Ohio. The Partnership completed the SUGS Acquisition on April 30, 2013 which was a reorganization of entities under common control.
	•	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 NGL 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 September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
	External Revenues
	Gathering and Processing	$	1,387		$	603		$	3,254		$	1,671
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	76			58			217			159
	Natural Resources	18			—			40			—
	Corporate	2			4			13			14
	Eliminations	—			—			—			—
	Total	$	1,483		$	665		$	3,524		$	1,844
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	3			4			11			11
	Natural Resources	—			—			—			—
	Corporate	—			—			—			—
	Eliminations	(3		)	(4		)	(11		)	(11		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	349		$	136		$	784		$	383
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	66			52			185			149
	Natural Resources	18			—			40			—
	Corporate	2			4			9			14
	Eliminations	(3		)	(4		)	(11		)	(11		)
	Total	$	432		$	188		$	1,007		$	535
	Operation and Maintenance
	Gathering and Processing	$	104		$	63		$	237		$	177
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	21			19			62			53
	Natural Resources	4			—			9			—
	Corporate	1			—			2			1
	Eliminations	(1		)	(4		)	(10		)	(11		)
	Total	$	129		$	78		$	300		$	220
	The table below provides a reconciliation of total segment margin to income before income taxes:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
	Total segment margin	$	432		$	188		$	1,007		$	535
	Operation and maintenance	(129		)	(78		)	(300		)	(220		)
	General and administrative	(36		)	(13		)	(123		)	(64		)
	(Loss) gain on asset sales, net	(1		)	1			1			(1		)
	Depreciation, depletion and amortization	(122		)	(74		)	(384		)	(207		)
	Income from unconsolidated affiliates	53			37			143			103
	Interest expense, net	(86		)	(41		)	(220		)	(119		)
	Gain (loss) on debt refinancing, net	2			—			2			(7		)
	Other income and deductions, net	(2		)	24			(7		)	3
	Income before income taxes	$	111		$	44		$	119		$	23
The tables below provide amounts reflected in the condensed consolidated balance sheets for each segment:
Total Assets	September 30, 2014			December 31, 2013
Gathering and Processing	$	12,310		$	4,748
Natural Gas Transportation	1,132			991
NGL Services	1,145			1,070
Contract Services	1,977			1,897
Natural Resources	515			—
Corporate and Others	101			76
Total	$	17,180		$	8,782
Investments in Unconsolidated Affiliates	September 30, 2014			December 31, 2013
Gathering and Processing	$	83		$	36
Natural Gas Transportation	1,131			991
NGL Services	1,145			1,070
Natural Resources	12			—
Total	$	2,371		$	2,097

EquityBased_Compensation_Notes

Equity-Based Compensation (Notes)	9 Months Ended
	Sep. 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 $2 million was recorded in general and administrative expense for the three months ended September 30, 2014 and 2013, respectively, and $8 million and $5 million for the nine months ended September 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 nine months ended September 30, 2014:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	982,242		$	23.16
	Service condition grants	810,682		26.55
	Vested service condition	(6,610	)	25.88
	Forfeited service condition	(91,234	)	24.81
	Outstanding at end of period	1,695,080		$	24.68
	The Partnership expects to recognize $30 million of compensation expense related to non-vested phantom units over a weighted-average period of 3.2 years.

Fair_Value_Measures_Notes

Fair Value Measures (Notes)	9 Months Ended
	Sep. 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 September 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	$	5		$	5	$	—	$	2	$	2	$	—
	NGLs	3			3		—		2		2		—
	Condensate	4			4		—		—		—		—
	Total Assets	$	12		$	12	$	—	$	4	$	4	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	2		$	2	$	—	$	4	$	4	$	—
	NGLs	1			1		—		4		4		—
	Condensate	1			1		—		1		1		—
	Embedded derivatives in Series A Preferred Units	30			—		30		19		—		19
	Total Liabilities	$	34		$	4	$	30	$	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		September 30, 2014
	Credit Spread		4.06	%
	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.
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the nine months ended September 30, 2014. There were no transfers between the fair value hierarchy levels for the nine months ended September 30, 2014.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2013	$	19
	Change in fair value recorded in other income and deductions	11
	Net liability balance at September 30, 2014	$	30
	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 September 30, 2014 were $5.9 billion and $5.69 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)	9 Months Ended
	Sep. 30, 2014
Statement of Financial Position [Abstract]	'
Guarantees [Text Block]	'
	CONSOLIDATING GUARANTOR FINANCIAL INFORMATION
	ELG, Aqua - PVR, and ORS do not fully and unconditionally guarantee, on a joint and several basis, the Senior Notes issued and outstanding as of September 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 affiliates. ELG, Aqua - PVR, and ORS are included in the non-guarantor subsidiaries.
	The consolidating financial information for the Parent, Guarantor Subsidiaries, and Non Guarantor Subsidiaries are as follows:
		30-Sep-14
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	22		$	(7	)	$	15
	All other current assets	—			671			31			(1		)	701
	Property, plant, and equipment, net	—			8,759			321			(87		)	8,993
	Investments in subsidiaries	21,257			—			—			(21,257		)	—
	Investments in unconsolidated affiliates	—			2,207			—			164			2,371
	All other assets	—			5,100			—			—			5,100
	TOTAL ASSETS	$	21,257		$	16,737		$	374		$	(21,188	)	$	17,180
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	All other current liabilities	—			810			16			(1		)	825
	Long-term liabilities	5,801			763			3			(3		)	6,564
	Noncontrolling interest	—			—			—			117			117
	Total partners’ capital	15,456			15,164			355			(21,301		)	9,674
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	21,257		$	16,737		$	374		$	(21,188	)	$	17,180
		31-Dec-13
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	19		$	—		$	19
	All other current assets	—			366			15			—			381
	Property, plant, and equipment, net	—			4,244			174			—			4,418
	Investments in subsidiaries	10,446			—			—			(10,446		)	—
	Investments in unconsolidated affiliates	—			1,995			—			102			2,097
	All other assets	—			1,867			—			—			1,867
	TOTAL ASSETS	$	10,446		$	8,472		$	208		$	(10,344	)	$	8,782
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	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		$	8,472		$	208		$	(10,344	)	$	8,782
		Three Months Ended September 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,466		$	18		$	(1	)	$	1,483
	Operating costs, expenses, and other	—			1,334			9			(4		)	1,339
	Operating income	—			132			9			3			144
	Income from unconsolidated affiliates	—			52			—			1			53
	Interest expense, net	(85		)	(1		)	—			—			(86		)
	Gain (loss) on debt refinancing, net	2			—			—			—			2
	Equity in consolidated subsidiaries	190			—			—			(190		)	—
	Other income and deductions, net	(2		)	—			—			—			(2		)
	Income before income taxes	105			183			9			(186		)	111
	Income tax expense	2			2			—			—			4
	Net income	103			181			9			(186		)	107
	Net income attributable to noncontrolling interest	—			—			—			(4		)	(4		)
	Net income attributable to Regency Energy Partners LP	$	103		$	181		$	9		$	(190	)	$	103
	Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	103			181			9			(186		)	107
	Comprehensive income attributable to noncontrolling interest	—			—			—			4			4
	Comprehensive income attributable to Regency Energy Partners LP	$	103		$	181		$	9		$	(190	)	$	103
		Three Months Ended September 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	654		$	11		$	—		$	665
	Operating costs, expenses, and other	—			637			4			—			641
	Operating income	—			17			7			—			24
	Income from unconsolidated affiliates	—			37			—			—			37
	Interest expense, net	(37		)	(4		)	—			—			(41		)
	Equity in consolidated subsidiaries	52			—			—			(52		)	—
	Other income and deductions, net	25			(1		)	—			—			24
Income before income taxes	40			49			7			(52		)	44
Income tax benefit	—			2			—			—			2
Net income	40			47			7			(52		)	42
Net income attributable to noncontrolling interest	—			(4		)	—			1			(3		)
Net income attributable to Regency Energy Partners LP	$	40		$	43		$	7		$	(51	)	$	39
Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
Comprehensive income	40			47			7			(52		)	42
Comprehensive income attributable to noncontrolling interest	—			4			—			(1		)	3
Comprehensive income attributable to Regency Energy Partners LP	$	40		$	43		$	7		$	(51	)	$	39
	Nine Months Ended September 30, 2014
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Revenues	$	—		$	3,477		$	49		$	(2	)	$	3,524
Operating costs, expenses, and other	—			3,306			24			(7		)	3,323
Operating income	—			171			25			5			201
Income from unconsolidated affiliates	—			143			—			—			143
Interest expense, net	(206		)	(14		)	—			—			(220		)
Gain (loss) on debt refinancing, net	3			(1		)	—			—			2
Equity in consolidated subsidiaries	327			—			—			(327		)	—
Other income and deductions, net	(11		)	4			—			—			(7		)
Income before income taxes	113			303			25			(322		)	119
Income tax expense	3			—			1			—			4
Net income	110			303			24			(322		)	115
Net income attributable to noncontrolling interest	—			—			—			(11		)	(11		)
Net income attributable to Regency Energy Partners LP	$	110		$	303		$	24		$	(333	)	$	104
Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
Comprehensive income	110			303			24			(322		)	115
Comprehensive income attributable to noncontrolling interest	—			—			—			11			11
Comprehensive income attributable to Regency Energy Partners LP	$	110		$	303		$	24		$	(333	)	$	104
	Nine Months Ended September 30, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Revenues	$	—		$	1,825		$	19		$	—		$	1,844
Operating costs, expenses, and other	3			1,789			9			—			1,801
Operating (loss) income	(3		)	36			10			—			43
Income from unconsolidated affiliates	—			103			—			—			103
Interest expense, net	(106		)	(13		)	—			—			(119		)
Loss on debt refinancing, net	(7		)	—			—			—			(7		)
Equity in consolidated subsidiaries	135			—			—			(135		)	—
Other income and deductions, net	3			—			—			—			3
Income before income taxes	22			126			10			(135		)	23
Income tax benefit	—			(1		)	—			—			(1		)
Net income	22			127			10			(135		)	24
Net income attributable to noncontrolling interest	—			(4		)	—			—			(4		)
Net income attributable to Regency Energy Partners LP	$	22		$	123		$	10		$	(135	)	$	20
Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
Comprehensive income	22			127			10			(135		)	24
Comprehensive income attributable to noncontrolling interest	—			4			—			—			4
Comprehensive attributable to Regency Energy Partners LP	$	22		$	123		$	10		$	(135	)	$	20
	Nine Months Ended September 30, 2014
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Cash flows from operating activities	$	—		$	525		$	46		$	(1	)	$	570
Cash flows from investing activities	—			(1,747		)	(19		)	(8		)	(1,774		)
Cash flows from financing activities	—			1,222			(24		)	2			1,200
Change in cash	—			—			3			(7		)	(4		)
Cash at beginning of period	—			—			19			—			19
Cash at end of period	$	—		$	—		$	22		$	(7	)	$	15
	Nine Months Ended September 30, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
Cash flows from operating activities	$	—		$	374		$	7		$	—		$	381
Cash flows from investing activities	—			(1,019		)	(86		)	—			(1,105		)
Cash flows from financing activities	—			645			38			—			683
Change in cash	—			—			(41		)	—			(41		)
Cash at beginning of period	—			—			53			—			53
Cash at end of period	$	—		$	—		$	12		$	—		$	12

Organization_And_Summary_Of_Si1

Organization And Summary Of Significant Accounting Policies (Policy)	9 Months Ended
	Sep. 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; natural gas and NGL marketing and trading, 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)	9 Months Ended
	Sep. 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:
		Nine Months Ended September 30, 2013 (1)
	Revenues:
	Partnership	$	1,576
	SUGS	268
	Combined	$	1,844
	Net income (loss):
	Partnership	$	60
	SUGS	(36		)
	Combined	$	24
	(1) The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include four months of activity for the nine months ended September 30, 2013

Partners_Capital_and_Distribut1

Partners' Capital and Distributions (Tables)	9 Months Ended
	Sep. 30, 2014
Partners’ Capital and Distributions [Abstract]	'
Schedule of Stockholders Equity [Table Text Block]	'
	The change in common and Class F units during the nine months ended September 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	37,191		—
	Issuance of common units under the equity distribution agreements	5,442,878		—
	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	30,890,565		—
	Issuance of common units in connection with Eagle Rock Midstream Acquisition	8,245,859		—
	Balance - September 30, 2014	399,895,578		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
	September 30, 2014		November 7, 2014	November 14, 2014	$0.50

Income_Per_Limited_Partner_Uni1

Income Per Limited Partner Unit (Tables)	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Basic And Diluted Income 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 nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,
		2014							2013
		Income			Units		Per-Unit		Income			Units	Per-Unit
		(Numerator)			(Denominator)		Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amount allocated to common units	$	91		397,961,321		$	0.23	$	33		209,559,854	$	0.16
	Effect of Dilutive Securities:
	Common unit options	—			31,777				—			32,489
	Phantom units	—			737,205				—			435,606
	Series A Preferred Units	—			—				(23		)	2,047,571
	Diluted income per unit	$	91		398,730,303		$	0.23	$	10		212,075,520	$	0.05
		Nine Months Ended September 30,
		2014							2013
		Income			Units		Per-Unit		Income			Units	Per-Unit
		(Numerator)			(Denominator)		Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amount allocated to common units	$	74		328,989,245		$	0.22	$	40		191,334,032	$	0.21
	Effect of Dilutive Securities:
	Common unit options	—			27,574				—			23,931
	Phantom units	—			590,034				—			351,811
	Diluted income per unit	$	74		329,606,853		$	0.22	$	40		191,709,774	$	0.21
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 September 30, 2014		Nine Months Ended September 30, 2014		Nine Months Ended September 30, 2013
	Series A Preferred Units	2,061,191		2,057,716		2,047,571

Acquisitions_Tables

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2014
Business Acquisition, Pro Forma Information [Table Text Block]	'
	The following unaudited pro forma consolidated results of operations for the three and nine months ended September 30, 2014 and 2013 are presented as if the PVR, Hoover and Eagle Rock Midstream 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. Actual results for the three months ended September 30, 2014 include PVR, Hoover and the Eagle Rock midstream business for the entire period.
		Three Months Ended September 30,					Nine Months Ended September 30,
		2014		2013			2014			2013
	Revenues	$	1,483	$	1,230		$	4,354		$	3,453
	Net income (loss) attributable to the Partnership	103		(6		)	(23		)	(119		)
	Basic net income (loss) per Limited Partner unit	$	0.23	$	(0.01	)	$	(0.23	)	$	(0.01	)
	Diluted net income (loss) per Limited Partner unit	$	0.23	$	(0.01	)	$	(0.23	)	$	(0.01	)
Eagle Rock [Member]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	Management’s evaluation of the assigned fair values is ongoing. The table below represents a preliminary allocation of the total purchase price:
	Assets	At July 1, 2014
	Current assets	$	115
	Property, plant and equipment	1,329
	Other long-term assets	4
	Total Assets Acquired	$	1,448
	Liabilities
	Current liabilities	$	109
	Long-term debt	499
	Long-term liabilities	12
	Total Liabilities Assumed	$	620
	Net Assets Acquired	$	828
PVR [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 March 21, 2014
	Current assets	$	149
	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	185
	Investments in unconsolidated affiliates	62
	Intangible assets	2,717
	Goodwill (1)	370
	Other long-term assets	18
	Total Assets Acquired	$	6,032
	Liabilities
	Current liabilities	$	168
	Long-term debt	1,788
	Premium related to senior notes	99
	Long-term liabilities	30
	Total Liabilities Assumed	$	2,085
	Net Assets Acquired	$	3,947
	(1) Goodwill is reported in the Gathering and Processing segment.
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	60
	Compression equipment	16
	Gas plants and buildings	12
	Other property, plant, and equipment	23
	Construction in process	6
	Intangible assets	148
	Goodwill (1)	30
	Total Assets Acquired	$	300
	Liabilities
	Accounts payable and accrued liabilities	$	5
	Asset retirement obligation	2
	Total Liabilities Assumed	$	7
	Net Assets Acquired	$	293
	(1) Goodwill is reported in the Gathering and Processing segment.

Investment_In_Unconsolidated_A1

Investment In Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 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 September 30, 2014 and December 31, 2013 is as follows:
		September 30, 2014			December 31, 2013
	HPC	$	428		$	442
	MEP	703			548
	Lone Star	1,145			1,070
	Ranch JV	35			36
	Aqua - PVR	47			—
	Coal Handling	12			—
	Sweeny JV	1			—
	Grey Ranch	—			1
	Total	$	2,371		$	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 nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	—		$	15		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(14		)	(17		)	(37		)	(7		)	(1		)	(2		)
	Share of earnings of unconsolidated affiliates’ net income (loss)	9			11			31			3			(1		)	1
	Amortization of excess fair value of investment	(1		)	—			—			—			—			—
		Three Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	51		$	1
	Distributions from unconsolidated affiliates	(196		)	(18		)	(16		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	9			11			18			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Nine Months Ended September 30, 2014
		HPC			MEP (2)			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Contributions to unconsolidated affiliates	$	—		$	175		$	86		$	—		$	—		$	—
	Distributions from unconsolidated affiliates	(35		)	(54		)	(94		)	(8		)	(1		)	(2		)
	Share of earnings of unconsolidated affiliates’ net income (loss)	25			33			83			7			(2		)	1
	Amortization of excess fair value of investment	(4		)	—			—			—			—			—
		Nine Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	100		$	2
	Distributions from unconsolidated affiliates	(226		)	(56		)	(56		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	28			31			48			—
	Amortization of excess fair value of investment	(4		)	—			—			—
	(1) The Partnership received a non-recurring return of capital of $185 million from HPC in September 2013.
	(2) The Partnership paid $175 million to MEP in September 2014.
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 nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	39		$	64		$	1,166		$	10		$	2		$	3
	Operating income (loss)	21			33			105			8			(1		)	1
	Net income (loss)	19			21			104			8			(1		)	1
		Three Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	66		$	537		$	4
	Operating income	19			34			61			1
	Net income	18			21			61			1
		Nine Months Ended September 30, 2014
		HPC			MEP			Lone Star			Ranch JV			Aqua - PVR			Coal Handling
	Total revenues	$	113		$	196		$	2,859		$	30		$	2		$	6
	Operating income (loss)	59			102			279			22			(4		)	3
	Net income (loss)	50			65			276			21			(4		)	3
		Nine Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	116		$	194		$	1,320		$	10
	Operating income	58			101			162			2
	Net income	56			63			160			2

Derivative_Instruments_Tables

Derivative Instruments (Tables)	9 Months Ended
	Sep. 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 September 30, 2014 and December 31, 2013 are detailed below:
		Assets						Liabilities
		September 30, 2014			December 31, 2013			September 30, 2014		December 31, 2013
	Derivatives not designated as cash flow hedges
	Current amounts
	Commodity contracts	$	11		$	3		$	3	$	9
	Long-term amounts
	Commodity contracts	1			1			1		—
	Embedded derivatives in Series A Preferred Units	—			—			30		19
	Total derivatives	$	12		$	4		$	34	$	28
Derivative Instruments, Gain (Loss) [Table Text Block]	'
	The Partnership’s statements of operations for the three and nine months ended September 30, 2014 and 2013 were impacted by derivative instruments activities as follows:
				Three Months Ended September 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		$	(10	)
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(1		)	24
				$	17		$	14
				Nine Months Ended September 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
	Embedded derivatives in Series A Preferred Units		Other income &  deductions, net	(11		)	2
				$	(11	)	$	2

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 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:
		September 30, 2014			December 31, 2013
	Senior notes	$	5,688		$	2,800
	Revolving loans	689			510
	Unamortized premium and discounts	50			—
	Long-term debt	$	6,427		$	3,310
	Availability under revolving credit facility:
	Total credit facility limit	$	1,500		$	1,200
	Revolving loans	(689		)	(510		)
	Letters of credit	(25		)	(14		)
	Total available	$	786		$	676
Long-Term Debt Maturities	'
	Long-term debt maturities as of September 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		5,777
	Total *		$	6,377
	*	Excludes a $70 million unamortized premium on the 2020 PVR Notes and the 2021 PVR Notes assumed by the Partnership and a $20 million unamortized discount on the combined 2022 Notes.

Commitments_And_Contingencies_1

Commitments And Contingencies (Tables)	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	The table below reflects the environmental liabilities recorded at September 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.
		September 30, 2014		December 31, 2013
	Current	$	2	$	2
	Noncurrent	8		6
	Total environmental liabilities	$	10	$	8

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions [Table Text Block]	'
	As of September 30, 2014 and December 31, 2013, details of the Partnership’s related party receivables and related party payables were as follows:
		September 30, 2014		December 31, 2013
	Related party receivables
	ETE and its subsidiaries	$	48	$	25
	HPC	1		1
	Ranch JV	—		2
	Other	3		—
	Total related party receivables	$	52	$	28
	Related party payables
	ETE and its subsidiaries	$	43	$	68
	HPC	1		1
	Total related party payables	$	44	$	69

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2014
Segment Information [Abstract]	'
Operating Results for Each Segment	'
	Results for each segment are shown below:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
	External Revenues
	Gathering and Processing	$	1,387		$	603		$	3,254		$	1,671
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	76			58			217			159
	Natural Resources	18			—			40			—
	Corporate	2			4			13			14
	Eliminations	—			—			—			—
	Total	$	1,483		$	665		$	3,524		$	1,844
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	3			4			11			11
	Natural Resources	—			—			—			—
	Corporate	—			—			—			—
	Eliminations	(3		)	(4		)	(11		)	(11		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	349		$	136		$	784		$	383
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	66			52			185			149
	Natural Resources	18			—			40			—
	Corporate	2			4			9			14
	Eliminations	(3		)	(4		)	(11		)	(11		)
	Total	$	432		$	188		$	1,007		$	535
	Operation and Maintenance
	Gathering and Processing	$	104		$	63		$	237		$	177
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	21			19			62			53
	Natural Resources	4			—			9			—
	Corporate	1			—			2			1
	Eliminations	(1		)	(4		)	(10		)	(11		)
	Total	$	129		$	78		$	300		$	220
Reconciliation of Total Segment Margin to Income (Loss) Before Income Taxes	'
	The table below provides a reconciliation of total segment margin to income before income taxes:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2014			2013			2014			2013
	Total segment margin	$	432		$	188		$	1,007		$	535
	Operation and maintenance	(129		)	(78		)	(300		)	(220		)
	General and administrative	(36		)	(13		)	(123		)	(64		)
	(Loss) gain on asset sales, net	(1		)	1			1			(1		)
	Depreciation, depletion and amortization	(122		)	(74		)	(384		)	(207		)
	Income from unconsolidated affiliates	53			37			143			103
	Interest expense, net	(86		)	(41		)	(220		)	(119		)
	Gain (loss) on debt refinancing, net	2			—			2			(7		)
	Other income and deductions, net	(2		)	24			(7		)	3
	Income before income taxes	$	111		$	44		$	119		$	23
Schedule Of Assets Related To Balance Sheet	'
	The tables below provide amounts reflected in the condensed consolidated balance sheets for each segment:
	Total Assets	September 30, 2014			December 31, 2013
	Gathering and Processing	$	12,310		$	4,748
	Natural Gas Transportation	1,132			991
	NGL Services	1,145			1,070
	Contract Services	1,977			1,897
	Natural Resources	515			—
	Corporate and Others	101			76
	Total	$	17,180		$	8,782
	Investments in Unconsolidated Affiliates	September 30, 2014			December 31, 2013
	Gathering and Processing	$	83		$	36
	Natural Gas Transportation	1,131			991
	NGL Services	1,145			1,070
	Natural Resources	12			—
	Total	$	2,371		$	2,097

EquityBased_Compensation_Table

Equity-Based Compensation (Tables) (Phantom Units)	9 Months Ended
	Sep. 30, 2014
Phantom Units	'
Phantom Units Activity	'
	The following table presents phantom units activity for the nine months ended September 30, 2014:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	982,242		$	23.16
	Service condition grants	810,682		26.55
	Vested service condition	(6,610	)	25.88
	Forfeited service condition	(91,234	)	24.81
	Outstanding at end of period	1,695,080		$	24.68

Fair_Value_Measures_Tables

Fair Value Measures (Tables)	9 Months Ended
	Sep. 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 September 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	$	5		$	5	$	—	$	2	$	2	$	—
	NGLs	3			3		—		2		2		—
	Condensate	4			4		—		—		—		—
	Total Assets	$	12		$	12	$	—	$	4	$	4	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	2		$	2	$	—	$	4	$	4	$	—
	NGLs	1			1		—		4		4		—
	Condensate	1			1		—		1		1		—
	Embedded derivatives in Series A Preferred Units	30			—		30		19		—		19
	Total Liabilities	$	34		$	4	$	30	$	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		September 30, 2014
	Credit Spread		4.06	%
Valuation Changes in Level 3 Derivatives	'
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the nine months ended September 30, 2014. There were no transfers between the fair value hierarchy levels for the nine months ended September 30, 2014.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2013	$	19
	Change in fair value recorded in other income and deductions	11
	Net liability balance at September 30, 2014	$	30

Consolidating_Guarantor_Financ1

Consolidating Guarantor Financial Information (Tables)	9 Months Ended
	Sep. 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-Sep-14
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	22		$	(7	)	$	15
	All other current assets	—			671			31			(1		)	701
	Property, plant, and equipment, net	—			8,759			321			(87		)	8,993
	Investments in subsidiaries	21,257			—			—			(21,257		)	—
	Investments in unconsolidated affiliates	—			2,207			—			164			2,371
	All other assets	—			5,100			—			—			5,100
	TOTAL ASSETS	$	21,257		$	16,737		$	374		$	(21,188	)	$	17,180
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	All other current liabilities	—			810			16			(1		)	825
	Long-term liabilities	5,801			763			3			(3		)	6,564
	Noncontrolling interest	—			—			—			117			117
	Total partners’ capital	15,456			15,164			355			(21,301		)	9,674
	TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$	21,257		$	16,737		$	374		$	(21,188	)	$	17,180
		31-Dec-13
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	ASSETS
	Cash	$	—		$	—		$	19		$	—		$	19
	All other current assets	—			366			15			—			381
	Property, plant, and equipment, net	—			4,244			174			—			4,418
	Investments in subsidiaries	10,446			—			—			(10,446		)	—
	Investments in unconsolidated affiliates	—			1,995			—			102			2,097
	All other assets	—			1,867			—			—			1,867
	TOTAL ASSETS	$	10,446		$	8,472		$	208		$	(10,344	)	$	8,782
	LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST
	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		$	8,472		$	208		$	(10,344	)	$	8,782
Condensed Income Statement [Table Text Block]	'
		Three Months Ended September 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,466		$	18		$	(1	)	$	1,483
	Operating costs, expenses, and other	—			1,334			9			(4		)	1,339
	Operating income	—			132			9			3			144
	Income from unconsolidated affiliates	—			52			—			1			53
	Interest expense, net	(85		)	(1		)	—			—			(86		)
	Gain (loss) on debt refinancing, net	2			—			—			—			2
	Equity in consolidated subsidiaries	190			—			—			(190		)	—
	Other income and deductions, net	(2		)	—			—			—			(2		)
	Income before income taxes	105			183			9			(186		)	111
	Income tax expense	2			2			—			—			4
	Net income	103			181			9			(186		)	107
	Net income attributable to noncontrolling interest	—			—			—			(4		)	(4		)
	Net income attributable to Regency Energy Partners LP	$	103		$	181		$	9		$	(190	)	$	103
	Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	103			181			9			(186		)	107
	Comprehensive income attributable to noncontrolling interest	—			—			—			4			4
	Comprehensive income attributable to Regency Energy Partners LP	$	103		$	181		$	9		$	(190	)	$	103
		Three Months Ended September 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	654		$	11		$	—		$	665
	Operating costs, expenses, and other	—			637			4			—			641
	Operating income	—			17			7			—			24
	Income from unconsolidated affiliates	—			37			—			—			37
	Interest expense, net	(37		)	(4		)	—			—			(41		)
	Equity in consolidated subsidiaries	52			—			—			(52		)	—
	Other income and deductions, net	25			(1		)	—			—			24
	Income before income taxes	40			49			7			(52		)	44
	Income tax benefit	—			2			—			—			2
	Net income	40			47			7			(52		)	42
	Net income attributable to noncontrolling interest	—			(4		)	—			1			(3		)
	Net income attributable to Regency Energy Partners LP	$	40		$	43		$	7		$	(51	)	$	39
	Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	40			47			7			(52		)	42
	Comprehensive income attributable to noncontrolling interest	—			4			—			(1		)	3
	Comprehensive income attributable to Regency Energy Partners LP	$	40		$	43		$	7		$	(51	)	$	39
		Nine Months Ended September 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	3,477		$	49		$	(2	)	$	3,524
	Operating costs, expenses, and other	—			3,306			24			(7		)	3,323
	Operating income	—			171			25			5			201
	Income from unconsolidated affiliates	—			143			—			—			143
	Interest expense, net	(206		)	(14		)	—			—			(220		)
	Gain (loss) on debt refinancing, net	3			(1		)	—			—			2
	Equity in consolidated subsidiaries	327			—			—			(327		)	—
	Other income and deductions, net	(11		)	4			—			—			(7		)
	Income before income taxes	113			303			25			(322		)	119
	Income tax expense	3			—			1			—			4
	Net income	110			303			24			(322		)	115
	Net income attributable to noncontrolling interest	—			—			—			(11		)	(11		)
	Net income attributable to Regency Energy Partners LP	$	110		$	303		$	24		$	(333	)	$	104
	Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
	Comprehensive income	110			303			24			(322		)	115
	Comprehensive income attributable to noncontrolling interest	—			—			—			11			11
	Comprehensive income attributable to Regency Energy Partners LP	$	110		$	303		$	24		$	(333	)	$	104
		Nine Months Ended September 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Revenues	$	—		$	1,825		$	19		$	—		$	1,844
	Operating costs, expenses, and other	3			1,789			9			—			1,801
	Operating (loss) income	(3		)	36			10			—			43
	Income from unconsolidated affiliates	—			103			—			—			103
	Interest expense, net	(106		)	(13		)	—			—			(119		)
Loss on debt refinancing, net	(7		)	—			—			—			(7		)
Equity in consolidated subsidiaries	135			—			—			(135		)	—
Other income and deductions, net	3			—			—			—			3
Income before income taxes	22			126			10			(135		)	23
Income tax benefit	—			(1		)	—			—			(1		)
Net income	22			127			10			(135		)	24
Net income attributable to noncontrolling interest	—			(4		)	—			—			(4		)
Net income attributable to Regency Energy Partners LP	$	22		$	123		$	10		$	(135	)	$	20
Total other comprehensive income	$	—		$	—		$	—		$	—		$	—
Comprehensive income	22			127			10			(135		)	24
Comprehensive income attributable to noncontrolling interest	—			4			—			—			4
Comprehensive attributable to Regency Energy Partners LP	$	22		$	123		$	10		$	(135	)	$	20
Condensed Cash Flow Statement [Table Text Block]	'
		Nine Months Ended September 30, 2014
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Cash flows from operating activities	$	—		$	525		$	46		$	(1	)	$	570
	Cash flows from investing activities	—			(1,747		)	(19		)	(8		)	(1,774		)
	Cash flows from financing activities	—			1,222			(24		)	2			1,200
	Change in cash	—			—			3			(7		)	(4		)
	Cash at beginning of period	—			—			19			—			19
	Cash at end of period	$	—		$	—		$	22		$	(7	)	$	15
		Nine Months Ended September 30, 2013
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated Partnership
	Cash flows from operating activities	$	—		$	374		$	7		$	—		$	381
	Cash flows from investing activities	—			(1,019		)	(86		)	—			(1,105		)
	Cash flows from financing activities	—			645			38			—			683
	Change in cash	—			—			(41		)	—			(41		)
	Cash at beginning of period	—			—			53			—			53
	Cash at end of period	$	—		$	—		$	12		$	—		$	12

Organization_And_Summary_Of_Si3

Organization And Summary Of Significant Accounting Policies Narrative (Details) (USD $)	Apr. 30, 2013	Sep. 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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues	$1,483	$665	$3,524	$1,844
Net income	107	42	115	24
Regency [Member]	'	'	'	'
Revenues	'	'	'	1,576
Net income	'	'	'	60
SUGS [Member]	'	'	'	'
Revenues	'	'	'	268
Net income	'	'	'	-36
Combined [Member]	'	'	'	'
Revenues	'	'	'	1,844
Net income	'	'	'	$24

Partners_Capital_and_Distribut2

Partners' Capital and Distributions Narrative (Details) (USD $)	1 Months Ended	3 Months Ended	9 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 31, 2014	Jun. 30, 2014	Sep. 30, 2014
Stock Issued During Period, Value, Acquisitions	'	'	800
Citi [Member]	'	'	'
Equity Distribution Agreement Maximum Aggregate Value Of Common Units Sold	'	'	200
Stock Issued During Period, Shares, Issued for Cash	'	'	34
Barclays [Member]	'	'	'
Equity Distribution Agreement Maximum Aggregate Value Of Common Units Sold	'	'	400
Stock Issued During Period, Shares, Issued for Cash	'	'	128
Remaining amount available to be issued under the Equity Distribution Agreement	'	'	272
ETE And Its Subsidiaries [Member]	'	'	'
Stock Issued During Period, Value, Acquisitions	400	'	'
Capital Units [Member]	'	'	'
Stock Issued During Period, Value, Acquisitions	'	'	800
Capital Units [Member] | ETE And Its Subsidiaries [Member]	'	'	'
Stock Issued During Period, Shares, New Issues	16,500,000	14,400,000	30,890,565
Stock Issued During Period, Value, New Issues	'	$400	'

Partners_Capital_and_Distribut3

Partners' Capital and Distributions Unit Activity (Details)

3 Months Ended

9 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Jul. 31, 2014

Jun. 30, 2014

Sep. 30, 2014

Sep. 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]

ETE And Its Subsidiaries [Member]

Eagle Rock [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Capital Unit [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited Partners' Capital Account, Units Outstanding

'

'

'

'

399,895,578

210,850,232

6,274,483

6,274,483

'

'

'

'

'

'

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

'

'

'

'

37,191

'

'

'

'

'

'

'

'

'

Issuance of common units under the equity distribution agreements

'

'

'

'

5,442,878

'

'

'

'

'

'

'

'

'

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

'

'

'

8,245,859

Issuance of common units to ETE Common Holdings

'

'

'

'

'

'

'

'

'

'

16,500,000

14,400,000

30,890,565

'

Partners_Capital_and_Distribut4

Partners' Capital and Distributions Quarterly Distributions of Available Cash (Details) (USD $)	3 Months Ended					9 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Quarterly Distributions of Available Cash [Abstract]	'	'	'	'	'	'	'
Dividends Payable, Date of Record	7-Nov-14	7-Aug-14	8-May-14	7-Feb-14	'	'	'
Dividends Payable, Date of Payment	14-Nov-14	14-Aug-14	15-May-14	14-Feb-14	'	'	'
Distributions per common unit	$0.50	$0.49	$0.48	$0.48	$0.47	$1.47	$1.40

Income_Per_Limited_Partner_Uni2

Income Per Limited Partner Unit Reconciliation of Numerator and Denominator of Basic and Diluted Earnings Per Common Unit (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Net income allocated to limited partners	$91	$33	$74	$40
Diluted income from continuing operations amount	91	10	74	40
Weighted average number of common units outstanding	397,961,321	209,559,854	328,989,245	191,334,032
Diluted weighted number of units outstanding	398,730,303	212,075,520	329,606,853	191,709,774
Basic income per common unit	$0.23	$0.16	$0.22	$0.21
Diluted income per common unit	$0.23	$0.05	$0.22	$0.21
Common unit options [Member]	'	'	'	'
Income allocated to dilutive securities	0	0	0	0
Incremental common shares attributable to options	31,777	32,489	27,574	23,931
Phantom Units [Member]	'	'	'	'
Income allocated to dilutive securities	0	0	0	0
Incremental common shares attributable to phantom units	737,205	435,606	590,034	351,811
Series A preferred units [Member]	'	'	'	'
Income allocated to dilutive securities	$0	($23)	'	'
Incremental common shares attributable to dilutive effect of conversion of preferred stock	0	2,047,571	'	'

Income_Per_Limited_Partner_Uni3

Income Per Limited Partner Unit Antidilutive Securities Excluded from Computations of Earnings Per Unit (Details) (Series A preferred units [Member])	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2013
Series A preferred units [Member]	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,061,191	2,057,716	2,047,571

Acquisitions_Narrative_Details

Acquisitions Narrative (Details) (USD $)

3 Months Ended

9 Months Ended

2 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

1 Months Ended

2 Months Ended

9 Months Ended

In Millions, except Share data, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Apr. 30, 2013

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Feb. 03, 2014

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 21, 2014

Sep. 30, 2014

Jul. 01, 2014

Jul. 31, 2014

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 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]

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

'

'

'

'

'

'

'

'

'

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

'

'

'

1,500

'

'

'

293

'

'

'

5,700

'

1,300

'

'

'

'

'

'

'

Partners' Capital Account, Units, Sold in Private Placement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,040,471

'

'

'

'

'

Business Combination, Acquisition Related Costs

'

'

'

'

'

184

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Retirement Obligation

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

1,483

665

3,524

1,844

'

'

11

26

'

'

302

653

'

472

'

'

'

'

'

'

'

'

Net income (loss) attributable to Regency Energy Partners LP

103

39

104

20

'

'

-2

2

'

'

84

119

'

18

'

'

'

'

'

'

'

'

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

'

'

$800

'

'

'

'

'

'

'

'

'

'

'

'

$400

'

$800

'

'

'

'

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

8,245,859

'

Number of Share Received in Exchange of Each Share

'

'

'

'

'

'

'

'

'

'

'

'

1.02

'

'

'

'

'

'

'

'

'

Acquisitions_Eagle_Rock_PPA_Ta

Acquisitions Eagle Rock PPA Table (Details) (Eagle Rock [Member], USD $)	Jul. 01, 2014
In Millions, unless otherwise specified
Eagle Rock [Member]	'
Current assets	$115
Property, plant and equipment	1,329
Other long-term assets	4
Total Assets Acquired	1,448
Current liabilities	109
Long-term debt	499
Long-term liabilities	12
Total Liabilities Assumed	620
Net Assets Acquired	$828

Acquisitions_PVR_PPA_Table_Det

Acquisitions PVR PPA Table (Details) (PVR [Member], USD $)	Mar. 21, 2014
In Millions, unless otherwise specified
Current assets	$149
Investments in unconsolidated affiliates	62
Intangible assets	2,717
Goodwill (1)	370	[1]
Other long-term assets	18
Total Assets Acquired	6,032
Current liabilities	168
Long-term debt	1,788
Premium related to senior notes	99
Long-term liabilities	30
Total Liabilities Assumed	2,085
Net Assets Acquired	3,947
Gathering and transmission systems	'
Property, plant and equipment	1,396
Compression equipment	'
Property, plant and equipment	342
Gas plants and buildings	'
Property, plant and equipment	110
Natural resources	'
Property, plant and equipment	454
Other property, plant and equipment	'
Property, plant and equipment	229
Construction in process	'
Property, plant and equipment	$185
[1]	(1) Goodwill is reported in the Gathering and Processing segment.

Acquisitions_Hoover_PPA_Table_

Acquisitions Hoover PPA Table (Details) (Hoover Energy [Member], USD $)	Feb. 03, 2014
In Millions, unless otherwise specified
Accounts receivable, net	$5
Intangible assets	148
Goodwill (1)	30	[1]
Total Assets Acquired	300
Accounts payable and accrued liabilities	5
Asset retirement obligation	2
Total Liabilities Assumed	7
Net Assets Acquired	293
Gathering and transmission systems	'
Property, plant and equipment	60
Compression equipment	'
Property, plant and equipment	16
Gas plants and buildings	'
Property, plant and equipment	12
Other property, plant, and equipment	'
Property, plant and equipment	23
Construction in process	'
Property, plant and equipment	$6
[1]	(1) Goodwill is reported in the Gathering and Processing segment.

Acquisitions_Pro_Forma_Results

Acquisitions Pro Forma Results of Operations Table (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Business Combinations [Abstract]	'	'	'	'
Revenues	$1,483	$1,230	$4,354	$3,453
Net income (loss) attributable to the Partnership	$103	($6)	($23)	($119)
Basic net income (loss) per Limited Partner unit	$0.23	($0.01)	($0.23)	($0.01)
Diluted net income (loss) per Limited Partner unit	$0.23	($0.01)	($0.23)	($0.01)

Investment_In_Unconsolidated_A2

Investment In Unconsolidated Affiliates Narrative (Details) (USD $)	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 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]	Sweeny JV [Member]	Grey Ranch JV [Member]
Ownership in affiliate	49.99%	50.00%	30.00%	33.33%	51.00%	50.00%	50.00%	50.00%
Equity Method Investment, Cash Settlement	'	'	'	'	'	'	'	$4
Loss on Sale of Equity Investment	'	'	'	'	'	'	'	($1)

Investment_In_Unconsolidated_A3

Investment In Unconsolidated Affiliates Carrying Value of Unconsolidated Affiliates (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Equity Method Investments	$2,371	$2,097
HPC [Member]	'	'
Equity Method Investments	428	442
MEP {Member]	'	'
Equity Method Investments	703	548
Lone Star {Member]	'	'
Equity Method Investments	1,145	1,070
Ranch JV {Member]	'	'
Equity Method Investments	35	36
Aqua - PVR [Member]	'	'
Equity Method Investments	47	0
Coal Handling [Member]	'	'
Equity Method Investments	12	0
Sweeny JV [Member]	'	'
Equity Method Investments	1	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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	'	$185	'	'
Distributions from unconsolidated affiliates	'	'	147	108
Share of earnings of unconsolidated affiliates’ net income (loss)	53	37	143	103
HPC [Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	0	0	0
Distributions from unconsolidated affiliates	-14	-196	-35	-226
Share of earnings of unconsolidated affiliates’ net income (loss)	9	9	25	28
Amortization of excess fair value of investment	-1	-1	-4	-4
MEP {Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	0	175	0
Distributions from unconsolidated affiliates	-17	-18	-54	-56
Share of earnings of unconsolidated affiliates’ net income (loss)	11	11	33	31
Amortization of excess fair value of investment	0	0	0	0
Lone Star {Member]	'	'	'	'
Contributions to unconsolidated affiliates	15	51	86	100
Distributions from unconsolidated affiliates	-37	-16	-94	-56
Share of earnings of unconsolidated affiliates’ net income (loss)	31	18	83	48
Amortization of excess fair value of investment	0	0	0	0
Ranch JV {Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	1	0	2
Distributions from unconsolidated affiliates	-7	-1	-8	-1
Share of earnings of unconsolidated affiliates’ net income (loss)	3	0	7	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	-1	'	-1	'
Share of earnings of unconsolidated affiliates’ net income (loss)	-1	'	-2	'
Amortization of excess fair value of investment	0	'	0	'
Coal Handling [Member]	'	'	'	'
Contributions to unconsolidated affiliates	0	'	0	'
Distributions from unconsolidated affiliates	-2	'	-2	'
Share of earnings of unconsolidated affiliates’ net income (loss)	1	'	1	'
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		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
HPC [Member]	'	'	'	'
Equity method investments, total revenues	$39	$38	$113	$116
Equity method investments, operating income (loss)	21	19	59	58
Equity method investments, net income (loss)	19	18	50	56
MEP {Member]	'	'	'	'
Equity method investments, total revenues	64	66	196	194
Equity method investments, operating income (loss)	33	34	102	101
Equity method investments, net income (loss)	21	21	65	63
Lone Star {Member]	'	'	'	'
Equity method investments, total revenues	1,166	537	2,859	1,320
Equity method investments, operating income (loss)	105	61	279	162
Equity method investments, net income (loss)	104	61	276	160
Ranch JV {Member]	'	'	'	'
Equity method investments, total revenues	10	4	30	10
Equity method investments, operating income (loss)	8	1	22	2
Equity method investments, net income (loss)	8	1	21	2
Aqua - PVR [Member]	'	'	'	'
Equity method investments, total revenues	2	'	2	'
Equity method investments, operating income (loss)	-1	'	-4	'
Equity method investments, net income (loss)	-1	'	-4	'
Coal Handling [Member]	'	'	'	'
Equity method investments, total revenues	3	'	6	'
Equity method investments, operating income (loss)	1	'	3	'
Equity method investments, net income (loss)	$1	'	$3	'

Derivative_Instruments_Narrati

Derivative Instruments Narrative (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Outstanding borrowings in interest rate risk	$689	$510
Maximum	'	'
Credit risk of derivatives	10	'
Reduction in credit risk of derivatives due to netting feature	$2	'

Derivative_Instruments_Schedul

Derivative Instruments Schedule Of Derivative Assets And Liabilities (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative Asset, Fair Value, Gross Asset	$12	$4
Derivative Liability, Fair Value, Gross Liability	34	28
Current | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	11	3
Derivative Liability, Fair Value, Gross Liability	3	9
Long Term [Member] | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	1	1
Derivative Liability, Fair Value, Gross Liability	1	0
Long Term [Member] | Derivatives Not Designated as Cash Flow Hedges [Member] | Embedded Derivatives in Series A Preferred Units [Member]	'	'
Derivative Asset, Noncurrent	0	0
Embedded Derivative, Fair Value of Embedded Derivative Liability	$30	$19

Derivative_Instruments_IS_Impa

Derivative Instruments I/S Impact of Derivative Instruments (Details) (Not Designated as Hedging Instrument [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Derivative, Gain (Loss) on Derivative, Net	$17	$14	($11)	$2
Commodity Derivatives | Revenues	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	18	-10	'	'
Embedded Derivatives in Series A Preferred Units [Member] | Other Income and Deductions, Net	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($1)	$24	($11)	$2

LongTerm_Debt_Narrative_Detail

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

3 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

0 Months Ended

Sep. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Feb. 28, 2014

Sep. 30, 2014

Feb. 28, 2014

Apr. 24, 2014

Mar. 31, 2014

Mar. 25, 2014

Jul. 31, 2014

Sep. 30, 2014

Mar. 31, 2014

Mar. 25, 2014

Apr. 23, 2014

Mar. 31, 2014

Jul. 31, 2014

Jul. 01, 2014

Oct. 28, 2014

Feb. 28, 2014

Feb. 28, 2014

Jul. 01, 2014

Oct. 29, 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]

Senior Notes Due Two Thousand Eighteen [Member]

Redemption Before December 1, 2021 [Member]

Redemption After December 1, 2021 [Member]

Eagle Rock [Member]

Subsequent Event [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]

Senior Notes Due Two Thousand Eighteen [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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of Credit, Increase in Letter of Credit Sublimit, Before

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of Credit, Increase in Letter of Credit Sublimit, After

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of Credit Issuance Threshold

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of Credit, Increase in Permitted Investments, Before

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of Credit, Increase in Permitted Investments, After

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

600,000,000

'

'

499,000,000

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

5.88%

'

8.25%

'

'

'

8.38%

'

'

6.50%

'

5.00%

'

'

'

8.38%

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt, Principal Portion

'

'

'

'

'

'

'

'

'

83,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

'

'

'

'

'

'

'

'

'

91,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Increase, Accrued Interest

'

'

'

'

'

'

'

'

'

8,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Redemption Price, Percentage

'

'

'

'

'

'

104.13%

'

101.00%

'

'

'

101.00%

'

'

'

'

'

'

'

'

103.44%

Debt Instrument Redemption Value

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

'

'

'

'

'

'

'

'

LongTerm_Debt_Partnerships_Lon

Long-Term Debt Partnership's Long-Term Debt Schedule (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'	'
Senior notes	$5,688	$2,800
Revolving loans	689	510
Unamortized premium and discounts	50	0
Long-term debt	6,427	3,310
Total credit facility limit	1,500	1,200
Availability under revolving loans	-689	-510
Letters of credit	-25	-14
Total available	$786	$676

LongTerm_Debt_LongTerm_Debt_Ma

Long-Term Debt Long-Term Debt Maturities Schedule (Details) (USD $)	Sep. 30, 2014
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'
2014 (remainder)	$0
2015	0
2016	0
2017	0
2018	600
Thereafter	5,777
Total	6,377	[1]
Debt Instrument, Unamortized Premium	70
Debt Instrument, Unamortized Discount	($20)
[1]	*Excludes a $70 million unamortized premium on the 2020 PVR Notes and the 2021 PVR Notes assumed by the Partnership and a $20 million unamortized discount on the combined 2022 Notes.

Commitments_And_Contingencies_2

Commitments And Contingencies Narrative (Details) (USD $)	1 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2014	Sep. 30, 2014
Environmental Remediation Expense	'	$0
NMED [Member]	'	'
Accrual for Environmental Loss Contingencies	'	0
PADEP [Member]	'	'
Litigation Settlement, Amount	'	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 $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]	'	'
Current environmental liabilities	$2	$2
Noncurrent environmental liabilities	8	6
Total enviromental liabilities	$10	$8

Related_Party_Transactions_Nar

Related Party Transactions Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Related Party Transaction, NGL Sales	$89	$11	$196	$23
General and administrative	36	13	123	64
ETE	'	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	1	2	4	9
Distribution Made to Limited Partner, Cash Distributions Paid	53	31	119	62
ETE | May Twenty Six Service Agreement	'	'	'	'
Management Fee, Amount Paid	10	'	'	'
ETP [Member]	'	'	'	'
Purchase of compression equipment	27	39	58	76
Lone Star {Member]	'	'	'	'
Related Party Transaction, NGL Sales	86	'	193	'
HPC [Member]	'	'	'	'
General and administrative	$3	$4	$11	$14

Related_Party_Transactions_Rel

Related Party Transactions Related Party Receivables and Payables (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Related party receivables	$52	$28
Related party payables	44	69
ETE And Its Subsidiaries [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	48	25
Related party payables	43	68
HPC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	1	1
Related party payables	1	1
Ranch JV {Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	0	2
Other Affiliates [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	$3	$0

Segment_Information_Narrative_

Segment Information Narrative (Details)	Sep. 30, 2014
ELG [Member]	'
Total general partner interest	60.00%
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%
Sweeny JV [Member]	'
Total general partner interest	50.00%
Aqua - PVR [Member]	'
Total general partner interest	51.00%
ORS [Member]	'
Total general partner interest	75.00%
Coal Handling [Member]	'
Total general partner interest	50.00%

Segment_Information_Operating_

Segment Information Operating Results for Each Segment (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
External Revenues	$1,483	$665	$3,524	$1,844
Intersegment Revenue	0	0	0	0
Segment Margin	432	188	1,007	535
Operation and maintenance	129	78	300	220
Gathering and Processing	'	'	'	'
External Revenues	1,387	603	3,254	1,671
Intersegment Revenue	0	0	0	0
Segment Margin	349	136	784	383
Operation and maintenance	104	63	237	177
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	76	58	217	159
Intersegment Revenue	3	4	11	11
Segment Margin	66	52	185	149
Operation and maintenance	21	19	62	53
Natural Resources	'	'	'	'
External Revenues	18	0	40	0
Intersegment Revenue	0	0	0	0
Segment Margin	18	0	40	0
Operation and maintenance	4	0	9	0
Corporate	'	'	'	'
External Revenues	2	4	13	14
Intersegment Revenue	0	0	0	0
Segment Margin	2	4	9	14
Operation and maintenance	1	0	2	1
Eliminations	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenue	-3	-4	-11	-11
Segment Margin	-3	-4	-11	-11
Operation and maintenance	($1)	($4)	($10)	($11)

Segment_Information_Reconcilia

Segment Information Reconciliation of Total Segment Margin to Income Before Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Segment Information [Abstract]	'	'	'	'
Total segment margin	$432	$188	$1,007	$535
Operation and maintenance	-129	-78	-300	-220
General and administrative	-36	-13	-123	-64
(Loss) gain on asset sales, net	-1	1	1	-1
Depreciation, depletion and amortization	-122	-74	-384	-207
Income from unconsolidated affiliates	53	37	143	103
Interest expense, net	-86	-41	-220	-119
Gain (loss) on debt refinancing, net	2	0	2	-7
Other income and deductions, net	-2	24	-7	3
INCOME BEFORE INCOME TAXES	$111	$44	$119	$23

Segment_Information_Total_Segm

Segment Information Total Segment Assets (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Total assets	$17,180	$8,782
Gathering and Processing	'	'
Segment Reporting Information	'	'
Total assets	12,310	4,748
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Total assets	1,132	991
NGL Services	'	'
Segment Reporting Information	'	'
Total assets	1,145	1,070
Contract Services	'	'
Segment Reporting Information	'	'
Total assets	1,977	1,897
Natural Resources	'	'
Segment Reporting Information	'	'
Total assets	515	0
Corporate and Others	'	'
Segment Reporting Information	'	'
Total assets	$101	$76

Segment_Information_Investment

Segment Information Investment in Unconsolidated Affiliates (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Equity Method Investments	$2,371	$2,097
Gathering and Processing	'	'
Segment Reporting Information	'	'
Equity Method Investments	83	36
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Equity Method Investments	1,131	991
NGL Services	'	'
Segment Reporting Information	'	'
Equity Method Investments	1,145	1,070
Natural Resources	'	'
Segment Reporting Information	'	'
Equity Method Investments	$12	$0

EquityBased_Compensation_Narra

Equity-Based Compensation Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Equity-Based Compensation [Abstract]	'	'	'	'
Partnership's LTIP units	5,865,584	'	5,865,584	'
Share-based Compensation	$3	$2	$8	$5
Partnership expects to recognize compensation expense	$30	'	$30	'
Non-vested phantom units period, in years	'	'	'3 years 2 months	'

EquityBased_Compensation_Phant

Equity-Based Compensation Phantom Units Activity (Details) (Phantom Units, USD $)	9 Months Ended
	Sep. 30, 2014
Phantom Units	'
Outstanding at the beginning of the period, Units	982,242
Service condition grants, Units	810,682
Vested service condition, Units	-6,610
Forfeited service condition, Units	-91,234
Outstanding at the end of period, Units	1,695,080
Outstanding at the beginning of the period, Weighted Average Grant Date Fair Value	$23.16
Service condition grants, Weighted Average Grant Date Fair Value	$26.55
Vested service condition, Weighted Average Grant Date Fair Value	$25.88
Forfeited service condition, Weighted Average Grant Date Fair Value	$24.81
Outstanding at the end of the period, Weighted Average Grant Date Fair Value	$24.68

Fair_Value_Measures_Narrative_

Fair Value Measures Narrative (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Measures [Abstract]	'	'
Debt Instrument, Fair Value Disclosure	$5,900	$2,830
Unsecured Long-term Debt, Noncurrent	$5,688	$2,800

Fair_Value_Measures_FV_of_Part

Fair Value Measures FV of Partnership's Derivative Assets And Liabilities (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Measurement, Assets	$12	$4
Fair Value Measurement, Liabilities	34	28
Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	12	4
Fair Value Measurement, Liabilities	4	9
Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	30	19
Natural Gas Transportation	'	'
Fair Value Measurement, Assets	5	2
Fair Value Measurement, Liabilities	2	4
Natural Gas Transportation | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	5	2
Fair Value Measurement, Liabilities	2	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	3	2
Fair Value Measurement, Liabilities	1	4
NGLs | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	3	2
Fair Value Measurement, Liabilities	1	4
NGLs | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
Condensate	'	'
Fair Value Measurement, Assets	4	0
Fair Value Measurement, Liabilities	1	1
Condensate | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	4	0
Fair Value Measurement, Liabilities	1	1
Condensate | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
Embedded derivatives in Series A Preferred Units	'	'
Embedded Derivatives in Series A Preferred Units	30	19
Embedded derivatives in Series A Preferred Units | Significant Observable Inputs (Level 2)	'	'
Embedded Derivatives in Series A Preferred Units	0	0
Embedded derivatives in Series A Preferred Units | Unobservable Inputs (Level 3)	'	'
Embedded Derivatives in Series A Preferred Units	$30	$19

Fair_Value_Measures_Significan

Fair Value Measures Significant Unobservable Inputs for FV Estimation of Embedded Derivatives (Details)	Sep. 30, 2014
Fair Value Measures [Abstract]	'
Fair Value, Embedded Derivatives Significant Unobservable Input, Credit Spread	4.06%

Fair_Value_Measures_Valuation_

Fair Value Measures Valuation Changes in Level 3 Derivatives (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Fair Value Measures [Abstract]	'
Beginning balance	$19
Change in fair value	11
Ending balance	$30

Consolidating_Guarantor_Financ2

Consolidating Guarantor Financial Information Condensed Balance Sheet (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	$15	$19	$12	$53
All other current assets	701	381	'	'
Property, plant, and equipment, net	8,993	4,418	'	'
Investments in subsidiaries	0	0	'	'
Investments in unconsolidated affiliates	2,371	2,097	'	'
All other assets	5,100	1,867	'	'
TOTAL ASSETS	17,180	8,782	'	'
All other current liabilities	825	475	'	'
Long-term liabilities	6,564	3,391	'	'
Noncontrolling interest	117	102	'	'
Total partners’ capital	9,674	4,814	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	17,180	8,782	'	'
Parent Company [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	0	0	0	0
All other current assets	0	0	'	'
Property, plant, and equipment, net	0	0	'	'
Investments in subsidiaries	21,257	10,446	'	'
Investments in unconsolidated affiliates	0	0	'	'
All other assets	0	0	'	'
TOTAL ASSETS	21,257	10,446	'	'
All other current liabilities	0	0	'	'
Long-term liabilities	5,801	2,832	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	15,456	7,614	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	21,257	10,446	'	'
Consolidation, Eliminations [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	-7	0	0	0
All other current assets	-1	0	'	'
Property, plant, and equipment, net	-87	0	'	'
Investments in subsidiaries	-21,257	-10,446	'	'
Investments in unconsolidated affiliates	164	102	'	'
All other assets	0	0	'	'
TOTAL ASSETS	-21,188	-10,344	'	'
All other current liabilities	-1	0	'	'
Long-term liabilities	-3	0	'	'
Noncontrolling interest	117	102	'	'
Total partners’ capital	-21,301	-10,446	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	-21,188	-10,344	'	'
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	22	19	12	53
All other current assets	31	15	'	'
Property, plant, and equipment, net	321	174	'	'
Investments in subsidiaries	0	0	'	'
Investments in unconsolidated affiliates	0	0	'	'
All other assets	0	0	'	'
TOTAL ASSETS	374	208	'	'
All other current liabilities	16	9	'	'
Long-term liabilities	3	0	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	355	199	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	374	208	'	'
Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'	'	'
Cash	0	0	0	0
All other current assets	671	366	'	'
Property, plant, and equipment, net	8,759	4,244	'	'
Investments in subsidiaries	0	0	'	'
Investments in unconsolidated affiliates	2,207	1,995	'	'
All other assets	5,100	1,867	'	'
TOTAL ASSETS	16,737	8,472	'	'
All other current liabilities	810	466	'	'
Long-term liabilities	763	559	'	'
Noncontrolling interest	0	0	'	'
Total partners’ capital	15,164	7,447	'	'
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$16,737	$8,472	'	'

Consolidating_Guarantor_Financ3

Consolidating Guarantor Financial Information Condensed Income Statement (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues	$1,483	$665	$3,524	$1,844
Operating costs, expenses, and other	1,339	641	3,323	1,801
Operating income (loss)	144	24	201	43
Income from unconsolidated affiliates	53	37	143	103
Interest expense, net	-86	-41	-220	-119
Gain (loss) on debt refinancing, net	2	0	2	-7
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	-2	24	-7	3
Income before income taxes	111	44	119	23
Income tax expense (benefit)	4	2	4	-1
Net income	107	42	115	24
Net income attributable to noncontrolling interest	-4	-3	-11	-4
Net income attributable to Regency Energy Partners LP	103	39	104	20
Total other comprehensive income	0	0	0	0
Comprehensive income	107	42	115	24
Comprehensive income attributable to noncontrolling interest	4	3	11	4
Comprehensive income attributable to Regency Energy Partners LP	103	39	104	20
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	-85	-37	-206	-106
Gain (loss) on debt refinancing, net	2	'	3	-7
Equity in consolidated subsidiaries	190	52	327	135
Other income and deductions, net	-2	25	-11	3
Income before income taxes	105	40	113	22
Income tax expense (benefit)	2	0	3	0
Net income	103	40	110	22
Net income attributable to noncontrolling interest	0	0	0	0
Net income attributable to Regency Energy Partners LP	103	40	110	22
Total other comprehensive income	0	0	0	0
Comprehensive income	103	40	110	22
Comprehensive income attributable to noncontrolling interest	0	0	0	0
Comprehensive income attributable to Regency Energy Partners LP	103	40	110	22
Guarantor Subsidiaries [Member]	'	'	'	'
Revenues	1,466	654	3,477	1,825
Operating costs, expenses, and other	1,334	637	3,306	1,789
Operating income (loss)	132	17	171	36
Income from unconsolidated affiliates	52	37	143	103
Interest expense, net	-1	-4	-14	-13
Gain (loss) on debt refinancing, net	0	'	-1	0
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	0	-1	4	0
Income before income taxes	183	49	303	126
Income tax expense (benefit)	2	2	0	-1
Net income	181	47	303	127
Net income attributable to noncontrolling interest	0	-4	0	-4
Net income attributable to Regency Energy Partners LP	181	43	303	123
Total other comprehensive income	0	0	0	0
Comprehensive income	181	47	303	127
Comprehensive income attributable to noncontrolling interest	0	4	0	4
Comprehensive income attributable to Regency Energy Partners LP	181	43	303	123
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Revenues	18	11	49	19
Operating costs, expenses, and other	9	4	24	9
Operating income (loss)	9	7	25	10
Income from unconsolidated affiliates	0	0	0	0
Interest expense, net	0	0	0	0
Gain (loss) on debt refinancing, net	0	'	0	0
Equity in consolidated subsidiaries	0	0	0	0
Other income and deductions, net	0	0	0	0
Income before income taxes	9	7	25	10
Income tax expense (benefit)	0	0	1	0
Net income	9	7	24	10
Net income attributable to noncontrolling interest	0	0	0	0
Net income attributable to Regency Energy Partners LP	9	7	24	10
Total other comprehensive income	0	0	0	0
Comprehensive income	9	7	24	10
Comprehensive income attributable to noncontrolling interest	0	0	0	0
Comprehensive income attributable to Regency Energy Partners LP	9	7	24	10
Consolidation, Eliminations [Member]	'	'	'	'
Revenues	-1	0	-2	0
Operating costs, expenses, and other	-4	0	-7	0
Operating income (loss)	3	0	5	0
Income from unconsolidated affiliates	1	0	0	0
Interest expense, net	0	0	0	0
Gain (loss) on debt refinancing, net	0	'	0	0
Equity in consolidated subsidiaries	-190	-52	-327	-135
Other income and deductions, net	0	0	0	0
Income before income taxes	-186	-52	-322	-135
Income tax expense (benefit)	0	0	0	0
Net income	-186	-52	-322	-135
Net income attributable to noncontrolling interest	-4	1	-11	0
Net income attributable to Regency Energy Partners LP	-190	-51	-333	-135
Total other comprehensive income	0	0	0	0
Comprehensive income	-186	-52	-322	-135
Comprehensive income attributable to noncontrolling interest	4	-1	11	0
Comprehensive income attributable to Regency Energy Partners LP	($190)	($51)	($333)	($135)

Consolidating_Guarantor_Financ4

Consolidating Guarantor Financial Information Condensed Cash Flow Statement (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Condensed Financial Statements, Captions [Line Items]	'	'
Cash flows from operating activities	$570	$381
Cash flows from investing activities	-1,774	-1,105
Cash flows from financing activities	1,200	683
Change in cash	-4	-41
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	15	12
Parent Company [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Cash flows from operating activities	0	0
Cash flows from investing activities	0	0
Cash flows from financing activities	0	0
Change in cash	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]	'	'
Cash flows from operating activities	525	374
Cash flows from investing activities	-1,747	-1,019
Cash flows from financing activities	1,222	645
Change in cash	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	0	0
Non-Guarantor Subsidiaries [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Cash flows from operating activities	46	7
Cash flows from investing activities	-19	-86
Cash flows from financing activities	-24	38
Change in cash	3	-41
Cash and cash equivalents at beginning of period	19	53
Cash and cash equivalents at end of period	22	12
Consolidation, Eliminations [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Cash flows from operating activities	-1	0
Cash flows from investing activities	-8	0
Cash flows from financing activities	2	0
Change in cash	-7	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	($7)	$0