PVR Partners, L. P. (PVR) 10-Q 29 Oct 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Oct. 22, 2013	Oct. 22, 2013	Oct. 22, 2013
		Common Units	Class B Units	Special Units
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	30-Sep-13
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Trading Symbol	PVR
Entity Registrant Name	PVR PARTNERS, L. P.
Entity Central Index Key	1144945
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		101,837,863	23,779,883	10,346,257

Consolidated_Statements_Of_Ope

Consolidated Statements Of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues
Natural gas	$92,005	$78,026	$282,830	$215,780
Natural gas liquids	104,585	96,237	298,563	316,161
Gathering fees	24,673	15,482	73,475	34,094
Trunkline fees	27,389	11,747	70,143	28,394
Coal royalties	20,816	28,760	66,990	91,150
Gain on sale of assets		31,292		31,292
Other	19,496	7,303	33,839	21,305
Total revenues	288,964	268,847	825,840	738,176
Expenses
Cost of gas purchased	163,824	147,246	489,106	453,543
Operating	17,506	17,587	50,026	47,530
General and administrative	13,402	11,531	40,359	34,574
Acquisition related costs				14,049
Impairments				124,845
Depreciation, depletion and amortization	47,133	31,992	138,032	84,301
Total expenses	241,865	208,356	717,523	758,842
Operating income (loss)	47,099	60,491	108,317	-20,666
Other income (expense)
Interest expense	-28,358	-20,288	-78,362	-45,616
Derivatives	-965	-1,524	-560	2,201
Other	112	104	1,238	329
Net income (loss)	$17,888	$38,783	$30,633	($63,752)
Earnings (loss) per common unit, basic and diluted	($0.09)	$0.16	($0.47)	($1.14)
Weighted average number of common units outstanding, basic and diluted	96,983	88,366	96,283	83,834

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (Loss) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net income (loss)	$17,888	$38,783	$30,633	($63,752)
Reclassification adjustment for derivative activities		-201		-523
Comprehensive income (loss)	$17,888	$38,582	$30,633	($64,275)

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$7,901	$14,713
Accounts receivable, net of allowance for doubtful accounts	136,279	133,546
Assets held for sale		11,450
Derivative assets	229
Other current assets	5,127	5,446
Total current assets	149,536	165,155
Property, plant and equipment	2,771,684	2,479,802
Accumulated depreciation, depletion and amortization	-605,592	-490,456
Net property, plant and equipment	2,166,092	1,989,346
Equity investments	57,863	97,553
Goodwill	70,283	70,283
Intangible assets (net of accumulated amortization of $64,340 and $41,452)	597,712	620,600
Other long-term assets	58,794	55,772
Total assets	3,100,280	2,998,709
Current liabilities
Accounts payable and accrued liabilities	159,225	197,034
Deferred income	5,886	3,788
Derivative liabilities	691
Total current liabilities	165,802	200,822
Deferred income	12,488	15,212
Other liabilities	18,488	20,256
Senior notes	1,300,000	900,000
Revolving credit facility	332,500	590,000
Partners' capital
Partners' capital	1,271,002	1,272,419
Total liabilities and partners' capital	3,100,280	2,998,709
Common Units
Partners' capital
Partners' capital	662,039	671,386
Class B Units
Partners' capital
Partners' capital	412,044	406,553
Special Units
Partners' capital
Partners' capital	$196,919	$194,480

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Intangible assets, accumulated amortization	$64,340	$41,452

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities
Net income (loss)	$17,888	$38,783	$30,633	($63,752)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Gain on sale of assets		-31,292		-31,292
Gain on sale of equity investment	-14,302		-14,302
Depreciation, depletion and amortization	47,133	31,992	138,032	84,301
Impairments				124,845
Derivative Contracts:
Total derivative (gains) losses	965	1,524	560	-2,201
Cash receipts (payments) to settle derivatives	-123	-1,332	-313	-8,578
Non-cash interest expense	1,917	1,589	5,399	4,217
Non-cash unit-based compensation	1,248	1,086	3,356	4,643
Equity earnings, net of distributions received	1,961	697	5,635	142
Other	-291	-231	-3,359	-929
Changes in operating assets and liabilities:
Accounts receivable	-3,397	-9,890	-3,401	3,908
Accounts payable and accrued liabilities	18,534	31,594	16,419	16,581
Deferred income	2,213	1,840	102	3,362
Other assets and liabilities	345	-210	352	-455
Net cash provided by operating activities	74,091	66,150	179,113	134,792
Cash flows from investing activities
Acquisitions		787	-2,334	-850,156
Additions to property, plant and equipment	-84,754	-173,455	-344,103	-348,449
Joint venture capital contributions	-500	-10,200	-10,700	-21,900
Proceeds from sale of assets	58,628	62,271	70,592	62,271
Other	246	268	2,118	908
Net cash used in investing activities	-26,380	-120,329	-284,427	-1,157,326
Cash flows from financing activities
Distributions to partners	-52,781	-46,833	-158,302	-128,516
Net proceeds (costs) from equity offering	124,643	-219	124,643	577,743
Proceeds from issuance of senior notes			400,000	600,000
Proceeds from borrowings	70,000	108,000	360,000	359,000
Repayments of borrowings	-195,000	-5,000	-617,500	-365,000
Cash paid for debt issuance costs	-158	-617	-9,695	-19,206
Other	-437		-644
Net cash provided by (used in) financing activities	-53,733	55,331	98,502	1,024,021
Net increase (decrease) in cash and cash equivalents	-6,022	1,152	-6,812	1,487
Cash and cash equivalents - beginning of period	13,923	8,975	14,713	8,640
Cash and cash equivalents - end of period	7,901	10,127	7,901	10,127
Supplemental disclosure:
Cash paid for interest	4,709	5,806	54,039	29,632
Noncash investing activities:
Other assets acquired related to acquisition				4,827
Other liabilities assumed related to acquisition		-430		33,499
Special units issued as consideration in an acquisition				$191,302

Consolidated_Statements_Of_Par

Consolidated Statements Of Partners' Capital (USD $)	Total	Common Units	Class B Units	Special Units	Accumulated Other Comprehensive Income (loss)
In Thousands
Beginning Balance at Dec. 31, 2011	$581,704	$580,961			$743
Beginning Balance (Shares) at Dec. 31, 2011		79,033
Unit-based compensation (in shares)		113
Unit-based compensation	3,648	3,648
Distributions paid, in shares			461
Distributions paid	-128,516	-128,516
Issuance of units (in shares)		9,009	21,379	10,346
Issuance of units	769,045	177,743	400,000	191,302
Net income (loss)	-63,752	-75,310	7,814	3,744
Other	-9	-9
Other comprehensive income (loss)	-523				-523
Ending Balance at Sep. 30, 2012	1,161,597	558,517	407,814	195,046	220
Ending Balance (Shares) at Sep. 30, 2012		88,155	21,840	10,346
Beginning Balance at Dec. 31, 2012	1,272,419	671,386	406,553	194,480
Beginning Balance (Shares) at Dec. 31, 2012		95,633	22,306	10,346
Unit-based compensation (in shares)		105
Unit-based compensation	2,352	2,352
Distributions paid, in shares			1,474
Distributions paid	-158,302	-158,302
Issuance of units (in shares)		5,500
Issuance of units	124,507	124,507
Net income (loss)	30,633	22,703	5,491	2,439
Other	-607	-607
Ending Balance at Sep. 30, 2013	$1,271,002	$662,039	$412,044	$196,919
Ending Balance (Shares) at Sep. 30, 2013		101,238	23,780	10,346

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	9 Months Ended
	Sep. 30, 2013
Organization and Basis of Presentation	1	Organization and Basis of Presentation
	PVR Partners, L.P. is a publicly traded Delaware master limited partnership, and its limited partner common units representing limited partner interests are listed on the New York Stock Exchange (“NYSE”) under ticker symbol “PVR.” As used in these Notes to Consolidated Financial Statements, the “Partnership,” “PVR,” “we,” “us” or “our” mean PVR Partners, L.P. and, where the context requires, includes our subsidiaries.
	We are principally engaged in the gathering, transportation and processing of natural gas and the management of coal and natural resource properties in the United States. We currently conduct operations in three business segments: (i) Eastern Midstream, (ii) Midcontinent Midstream and (iii) Coal and Natural Resource Management.
		•	Eastern Midstream — Our Eastern Midstream segment is engaged in providing natural gas gathering, transportation and other related services in Pennsylvania, Ohio and West Virginia. In addition, we own member interests in a joint venture that transports fresh water to natural gas producers.
		•	Midcontinent Midstream — Our Midcontinent Midstream segment is engaged in providing natural gas gathering, processing and other related services. These processing and gathering systems are located primarily in Oklahoma and Texas.
		•	Coal and Natural Resource Management — Our Coal and Natural Resource Management segment primarily involves the management and leasing of coal properties and the subsequent collection of royalties. We also earn revenues from other land management activities, such as selling standing timber, leasing coal-related infrastructure facilities and collecting oil and gas royalties.
	During the first quarter of 2013, we adopted Accounting Standard Update (“ASU”) 2013-02, Comprehensive Income (Topic 220). The new ASU requires us to disclose in a single location (either on the face of the statement of operations or in the notes) the effects of reclassifications out of accumulated other comprehensive income (“AOCI”). The new disclosure requirements were effective for the first quarter 2013 and apply prospectively. All of our AOCI amounts were reclassified in 2012 and no amounts remained as of December 31, 2012. Therefore, adoption of this ASU does not have an effect on our financials.
	Our Consolidated Financial Statements include the accounts of PVR and all of our wholly-owned subsidiaries. Investments in non-controlled entities over which we exercise significant influence are accounted for using the equity method. Intercompany balances and transactions have been eliminated in consolidation. Our Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America. These statements involve the use of estimates and judgments where appropriate. In the opinion of management, all adjustments, consisting of normal recurring accruals, considered necessary for a fair presentation of our Consolidated Financial Statements have been included.
	Management has evaluated all activities of PVR through the date upon which our Consolidated Financial Statements were issued and concluded that while no subsequent events have occurred that would require recognition in the Consolidated Financial Statements, there were subsequent events for which disclosure is required in the Notes to the Consolidated Financial Statements. See Note 12 to the Consolidated Financial Statements.
	All dollar and unit amounts presented in the tables to these Notes are in thousands unless otherwise indicated.

Divestitures

Divestitures	9 Months Ended
	Sep. 30, 2013
Divestitures	2	Divestitures
	As of December 31, 2012, we had $11.5 million of assets held for sale. This amount was separately stated in our Consolidated Balance Sheet in current assets. The assets represented a Midcontinent Midstream plant that we sold in the first quarter of 2013 for $12.0 million. A gain of $0.5 million was recorded in other revenues on the Consolidated Statement of Operations.
	On August 19, 2013, we sold our 25% membership interest in Thunder Creek Gas Services LLC, a joint venture that gathers and transports coalbed methane gas in Wyoming’s Powder River Basin. This Midcontinent Midstream investment was accounted for using the equity method of accounting, and had a carrying value of $44.3 million. The proceeds from the sale were $58.6 million, resulting in a gain of $14.3 million recorded in other revenues on the Consolidated Statement of Operations.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Measurements	3	Fair Value Measurements
	We present fair value measurements and disclosures applicable to both our financial and nonfinancial assets and liabilities that are measured and reported on a fair value basis. Fair value is an exit price representing the expected amount we would receive to sell an asset or pay to transfer a liability in an orderly transaction with market participants at the measurement date. We have followed consistent methods and assumptions to estimate the fair values as more fully described in our Annual Report on Form 10-K for the year ended December 31, 2012.
	Our financial instruments that are subject to fair value disclosure consist of cash and cash equivalents, accounts receivable, accounts payable, derivatives and long-term debt. At September 30, 2013, the carrying values of all of these financial instruments, except the long-term debt with fixed interest rates, approximated fair value. The fair value of floating-rate debt approximates the carrying amount because the interest rates paid are based on short-term maturities. The fair value of our fixed-rate long-term debt is estimated based on the published market prices for the same or similar issues (a Level 1 category fair value measurement). As of September 30, 2013, the fair value of our fixed-rate debt was $1.3 billion.
	Recurring Fair Value Measurements
	The following table summarizes the assets and liabilities measured at fair value on a recurring basis for our commodity-based derivative financial instruments:
						Fair Value Measurements at September 30, 2013, Using
	Description		Fair Value			Quoted Prices in		Significant Other			Significant
			Measurements at			Active Markets for		Observable Inputs			Unobservable
			September 30, 2013			Identical Assets		(Level 2)			Inputs (Level 3)
						(Level 1)
	Commodity derivative assets - current		$	229		$	—	$	229		$	—
	Commodity derivative liabilities - current			(691	)	$	—		(691	)	$	—
	Total		$	(462	)	$	—	$	(462	)	$	—
	We had no open derivative positions as of December 31, 2012; therefore, there are no recurring valuations presented as of December 31, 2012.
	We utilize swap derivative contracts to hedge against the variability in commodity prices. We determine the fair values of our commodity derivative agreements using discounted cash flows based on quoted forward prices for the respective commodities. Each is a Level 2 input. We use the income approach, using valuation techniques that convert future cash flows to a single discounted value.

Derivative_Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments	4	Derivative Instruments
	Commodity Derivatives
	We determine the fair values of our derivative agreements using third-party forward prices for the respective commodities as of the end of the reporting period and discount rates adjusted for the credit risk of our counterparties if the derivative is in an asset position and our own credit risk if the derivative is in a liability position. The following table sets forth our positions as of September 30, 2013 for commodities related to revenues:
			Average				Weighted Average				Fair Value at
			Volume				Swap Price				September 30,
			Per Day								2013
	Crude oil swap			(barrels	)			(per barrel	)
	Fourth quarter 2013			500			$	94.8			$	(309	)
	Natural gas swaps			(MMBtu	)			(per MMBtu	)
	Fourth quarter 2013			5,500			$	3.823				229
	Propane swap - OPIS Conway			(gallons	)			(per gallon	)
	Fourth quarter 2013			42,000			$	1.00875				(125	)
	Settlements to be paid in subsequent period											(257	)
	Interest Rate Swaps
	During the nine months ended September 30, 2013, we did not have any open Interest Rate Swap positions. Therefore, there are no fair value measurements to disclose. As of September 30, 2012 we reported a gain in accumulated other comprehensive income (“AOCI”) of $0.2 million related to the Interest Rate Swaps. In connection with periodic settlements and related reclassification of other comprehensive income, we recognized $0.5 million of net hedging losses on the Interest Rate Swaps in the derivatives line on the Consolidated Statements of Operations during the nine months ended September 30, 2012. See the following “Financial Statement Impact of Derivatives” section for the impact of the Interest Rate Swaps on our Consolidated Financial Statements.
	Financial Statement Impact of Derivatives
	The following table summarizes the effects of our derivative activities, as well as the location of gains (losses) on our Consolidated Statements of Operations for the periods presented:
			Location of gain (loss)		Three Months Ended								Nine Months Ended
			on derivatives recognized		September 30,								September 30,
			in statement of operations		2013				2012				2013			2012
	Derivatives not designated as hedging instruments:
	Commodity contracts		Derivatives		$	(965	)		$	(1,695	)		$	(560	)	$	1,879
	Interest rate contracts		Derivatives			—				171				—			322
	Total increase (decrease) in net income resulting from derivatives				$	(965	)		$	(1,524	)		$	(560	)	$	2,201
	Realized and unrealized derivative impact:
	Cash received (paid) for commodity and interest rate contract settlements		Derivatives		$	(123	)		$	(1,332	)		$	(98	)	$	(8,578	)
	Unrealized derivative gains (losses)		Derivatives			(842	)			(192	)			(462	)		10,779
	Total increase (decrease) in net income resulting from derivatives				$	(965	)		$	(1,524	)		$	(560	)	$	2,201
	As of December 31, 2012, we had no open derivative positions. There were two settled but not paid commodity derivative positions in accounts payable amounting to $0.2 million at December 31, 2012. The following table summarizes the fair value of our derivative instruments, as well as the locations of these instruments on our Consolidated Balance Sheets for the new commodity hedges entered into during the period presented:
					Fair Values as of
					September 30, 2013
			Balance Sheet Location		Derivative				Derivative
					Assets				Liabilities
	Derivatives not designated as hedging instruments:
	Commodity contracts		Derivative assets/liabilities - current			229				691
	Total derivatives not designated as hedging instruments				$	229			$	691
	Total fair value of derivative instruments				$	229			$	691
	See Note 3, “Fair Value Measurements” for a description of how the above financial instruments are valued.
	As of September 30, 2013, we did not own derivative instruments that were classified as fair value hedges or trading securities. In addition, as of September 30, 2013, we did not own derivative instruments containing credit risk contingencies.

Equity_Investments

Equity Investments	9 Months Ended
	Sep. 30, 2013
Equity Investments	5	Equity Investments
	In accordance with the equity method of accounting, net of eliminations we recognized earnings from all equity investments in the aggregate of $0.9 million and $3.8 million for the nine months ended September 30, 2013 and 2012, with a corresponding increase in the investment. The joint ventures generally pay quarterly distributions on their cash flow. We received distributions of $6.5 million and $4.0 million for the nine months ended September 30, 2013 and 2012, with a corresponding decrease in the investment. Equity earnings related to our joint venture interests are recorded in other revenues on the Consolidated Statements of Operations. The equity investments for all joint ventures are included in the equity investments caption on the Consolidated Balance Sheets.
	As noted in Note 2 Divestitures, we sold our 25% membership interest in Thunder Creek Gas Services LLC, a joint venture that gathers and transports coalbed methane gas in Wyoming’s Powder River Basin. This Midcontinent Midstream investment had a carrying value of $44.3 million. The proceeds from the sale were $58.6 million, resulting in a gain of $14.3 million recorded in other revenues on the Consolidated Statement of Operations.
	Financial statements from our investees are not sufficiently timely for us to apply the equity method currently. Therefore, we record our share of earnings or losses of an investee from the most recently available financial statements, which are usually on a one-month delay. This delay in reporting is consistent from period to period.
	Summarized financial information of unconsolidated equity investments is as follows for the periods presented:
			August 31,		November 30,
			2013		2012
	Current assets		$	22,682	$	55,351
	Noncurrent assets		$	111,288	$	273,158
	Current liabilities		$	15,749	$	38,188
	Noncurrent liabilities		$	1,720	$	3,933
			Nine Months Ended August 31,
			2013		2012
	Revenues		$	34,447	$	42,772
	Expenses		$	30,107	$	29,190
	Net income		$	4,340	$	13,582

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Long-Term Debt	6	Long-Term Debt
	Revolver
	On February 21, 2013, we entered into the third amendment to the amended and restated revolving credit agreement (the “Revolver”) modifying the Revolver’s Maximum Leverage Ratio covenant to allow us to maintain a ratio of Consolidated Total Indebtedness (as defined in the Revolver amendment), calculated as of the end of each fiscal quarter for the four quarters then ended, of not more than (i) 5.50 to 1.0 commencing with the fiscal period ending September 30, 2013 through the fiscal period ending December 31, 2013; and (ii) 5.25 to 1.0 commencing with the fiscal period ending March 31, 2014, and for each fiscal period thereafter.
	Our Revolver allows for adjustments to Consolidated EBITDA (as defined in the Revolver) for material capital projects which exceed $10.0 million. The adjustments to Consolidated EBITDA have certain limitations and are approved by PNC Bank, as administrative agent to the Revolver.
	As of September 30, 2013, net of outstanding indebtedness of $332.5 million and letters of credit of $10.4 million, we had remaining borrowing capacity of $657.1 million on the Revolver. The weighted average interest rate on borrowings outstanding under the Revolver during the nine months ended September 30, 2013 was approximately 3.4%. We do not have a public rating for the Revolver. As of September 30, 2013, we were in compliance with all covenants under the Revolver.
	Senior Notes
	In May 2013, we sold $400.0 million of senior notes due on May 15, 2021 in a private placement with an annual interest rate of 6.5% (“6.5% Senior Notes”), which is payable semi-annually in arrears on May 15 and November 15 of each year beginning on November 15, 2013. The 6.5% Senior Notes were sold at par, equating to an effective yield to maturity of approximately 6.5%. The net proceeds from the sale of the 6.5% Senior Notes of approximately $391.0 million, after deducting fees and expenses of approximately $9.0 million, were used to repay borrowings under the Revolver. They are fully and unconditionally guaranteed by our existing and future domestic subsidiaries, subject to certain exceptions. The 6.5% Senior Notes are senior to any subordinated indebtedness, and are effectively subordinated to all of our secured indebtedness including the Revolver to the extent of the collateral securing that indebtedness.
	We also have $300 million of 8.25% Senior Notes, issued in April 2010 and due April 2018, and $600 million of 8.375% Senior Notes, issued in May 2012 and due June 2020.
	The 8.25% Senior Notes are unsecured obligations of PVR Partners, L.P. and Penn Virginia Resource Finance Corporation (“Finance Corp”). The 8.375% Senior Notes and the 6.5% Senior Notes are unsecured obligations of PVR Partners, L.P. and Penn Virginia Resource Finance Corporation II (“Finance Corp II”). Finance Corp and Finance Corp II are finance subsidiaries 100% owned by PVR Partners, L.P. Finance Corp, Finance Corp II, and PVR Partners, L.P. do not have any material independent assets or operations. The 8.25% Senior Notes, 8.375% Senior Notes and 6.5% Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by our other existing and future domestic restricted subsidiaries, subject to certain exceptions. The guarantees are joint and several and all subsidiary guarantors are 100% owned by PVR Partners, L.P. There are no significant restrictions on the ability of PVR, Finance Corp or Finance Corp II or any guarantor of the Senior Notes to obtain funds from their subsidiaries by dividend or loan.

Partners_Capital_and_Distribut

Partners' Capital and Distributions	9 Months Ended
	Sep. 30, 2013
Partners' Capital and Distributions	7	Partners’ Capital and Distributions
	As of September 30, 2013, partners’ capital consisted of 101.2 million common units, 10.3 million Special Units and 23.8 million Class B Units. We will pay distributions on November 13, 2013 with respect to the quarter ended September 30, 2013.
	Equity Offering
	In September 2013, we issued 5.5 million common units representing limited partner interest in PVR in a registered public offering. Total net proceeds of approximately $124.5 million, after deducting estimated fees and expenses and underwriting discounts and commissions totaling approximately $2.0 million, were used to repay a portion of the Revolver.
	At The Market (“ATM”) Equity Program
	An ATM program is an alternative way of raising capital by issuing equity through existing markets over a period of time. The flexibility of timing the issuance of units helps us to match demand for capital with the supply by controlling the number of units issued. Additionally, it reduces the volatility of unit price by avoiding issuance of a large number of common units. In August 2013 we issued our prospectus supplement relating to the issuance and sale from time to time of common units representing limited partner interests in PVR, or common units, having an aggregate offering price of up to $150.0 million through one or more sales agents. These sales, if any, will be made pursuant to the terms of the ATM equity offering sales agreement between us and the sales agents. The compensation of sales agents for the sales of common units shall not exceed 2.0% of the gross sales price per common unit. The net proceeds from any sales under this ATM program will be used for general partnership purposes, which may include, among other things, repayment of indebtedness, acquisitions, capital expenditures and additions to working capital. As of September 30, 3013, no sales have been made under the ATM program.
	Special Units
	The Special Units convert to common units on the first business day after the record date for distributions with respect to the quarter ended September 30, 2013. Therefore, conversion of the Special Units to common units will occur on November 7, 2013. Absent an early conversion event, the Special Units will not be entitled to accrue distributions until the quarter commencing on October 1, 2013. If the Special Units would have been entitled to accrue and receive the same per unit quarterly cash distributions to which the holders of our common units are entitled with respect to the quarter ended September 30, 2013, we would pay an aggregate of $5.7 million in distributions to the holders of the Special Units on November 13, 2013.
	Class B Units
	We will pay distributions to the holders of the Class B Units with respect to the quarter ended September 30, 2013 by issuing an aggregate of 525,624 additional Class B Units. If we were to pay distributions to the holders of the Class B Units in cash, rather than in additional Class B Units, at the same per unit quarterly cash distribution rate to which the holders of our common units are entitled with respect to the quarter ended September 30, 2013, the amount of cash distributions that would have been attributable to the Class B Units was $13.1 million.
	Net Income (Loss) per Common Unit
	The following table reconciles net income (loss) and weighted average common units used in computing basic and diluted net income (loss) per common unit (in thousands, except per unit data):
			Three Months Ended						Nine Months Ended
			September 30,						September 30,
			2013			2012			2013			2012
	Net income (loss)		$	17,888		$	38,783		$	30,633		$	(63,752	)
	Less:
	Distributions to participating securities			(13,124	)		(11,814	)		(38,577	)		(17,534	)
	Recognition of beneficial conversion feature (1)			(20,106	)		(17,120	)		(58,881	)		(28,174	)
	Participating securities’ allocable share of undistributed net loss			6,621			3,969			21,898			14,109
	Net income (loss) allocable to common units, basic and diluted		$	(8,721	)	$	13,818		$	(44,927	)	$	(95,351	)
	Weighted average number of common units outstanding, basic and diluted			96,983			88,366			96,283			83,834
	Net income (loss) per common unit, basic and diluted		$	(0.09	)	$	0.16		$	(0.47	)	$	(1.14	)
	-1	Special Units and Class B Units were issued at prices below the market price of the common units into which they are convertible. The aggregate discount of $139.2 million represents a beneficial conversion feature which is considered a non-cash distribution that will be distributed ratably using the effective yield method over the period the Special Units and Class B Units are outstanding. The impact of the beneficial conversion feature is included as distributed income to Class B Units and Special Units with a corresponding reduction in net income allocable to common units in the calculation of net income loss per common unit for the three and nine months ended September 30, 2013 and 2012.
	Basic net income (loss) per common unit is computed by dividing net income (loss) allocable to common units by the weighted average number of common units outstanding and vested deferred common units outstanding during the period. Diluted net income (loss) per common unit is computed by dividing net income (loss) allocable to common units by the weighted average number of common units outstanding and vested deferred common units outstanding during the period and, when dilutive, Class B Units, Special Units, and phantom units. The following table presents the weighted average number of each class of participating securities that were excluded from the diluted net income (loss) per common unit calculation because the inclusion of these units would have had an antidilutive effect:
			Three Months Ended						Nine Months Ended
			September 30,						September 30,
			2013			2012			2013			2012
	Special units			10,346			10,346			10,346			5,173
	Class B units			23,621			21,620			23,129			10,770
	Phantom units			78			73			70			51
				34,045			32,039			33,545			15,994
	Cash Distributions
	We distribute 100% of Available Cash (as defined in our partnership agreement) within 45 days after the end of each quarter to common unitholders of record. Available Cash is generally defined as all of our cash and cash equivalents on hand at the end of each quarter less reserves established by our general partner for future requirements. Our general partner has the discretion to establish cash reserves that are necessary or appropriate to (i) provide for the proper conduct of our business, (ii) comply with applicable law, any of our debt instruments or any other agreements and (iii) provide funds for distributions to unit holders for any one or more of the next four quarters.
	During the three and nine months ended September 30, 2013, we paid cash distributions of $52.8 million and $158.3 million.
	During the three and nine months ended September 30, 2012, we paid cash distributions of $46.8 million and $128.5 million.
	On November 13, 2013, we will pay a $0.55 per unit quarterly distribution to common unit holders of record on November 6, 2013.

UnitBased_Compensation

Unit-Based Compensation	9 Months Ended
	Sep. 30, 2013
Unit-Based Compensation	8	Unit-Based Compensation
	The PVR GP, LLC Sixth Amended and Restated Long-Term Incentive Plan (the “LTIP”) permits the grant of common units, deferred common units, unit options, restricted units and phantom units to employees and directors of our general partner and its affiliates. Common units and deferred common units granted under the LTIP are immediately vested, and we recognize compensation expenses related to those grants on the grant date. Restricted units and the time-based and performance-based phantom units granted under the LTIP generally vest over a three-year period, and we recognize compensation expense related to those grants on a straight-line basis over the vesting period. Compensation expense related to these grants is recorded in the general and administrative expenses caption on our Consolidated Statements of Operations. During the nine months ended September 30, 2013, we granted 288 thousand phantom units at a weighted average grant-date fair value of $23.19 per unit including 186 thousand time-based phantom units and 102 thousand performance-based phantom units.
	Time-based phantom units generally vest over a three-year period, with one-third vesting in each year. Certain of the time-based phantom units vested during the nine months ended September 30, 2013. A portion of the vested units was withheld for payroll taxes with the recipient receiving the net vested units. The fair value of time-based phantom units is calculated based on the grant-date unit price. Time-based phantom units are generally entitled to non-forfeitable distribution rights which are paid quarterly along with the common unit distributions.
	Performance-based phantom units cliff-vest at the end of a three-year period. The number of units that could vest ranges from 0% to 200% of the number of performance-based phantom units initially granted and depends on the outcome of unit market performance compared to peers and, for certain grants, key results of operations metrics. Performance-based phantom units are entitled to forfeitable distribution equivalent rights which accumulate over the term of the units and will be paid in cash to the grantees at the date of vesting. The fair value of each performance-based phantom unit granted in 2013 was estimated as $17.60 using a Monte Carlo simulation approach that uses the assumptions noted in the following table. Expected volatilities are based on historical changes in the market value of our common units. We base the risk-free interest rate on the U.S. Treasury rate for the week of the grant having a term equal to the expected life of the phantom units, continuously compounded.
			2013
	Expected volatility			28.2	%
	Expected life			2.7 years
	Risk-free interest rate			0.31	%
	In connection with the normal three-year vesting of phantom units, as well as common unit and deferred common unit awards, we recognized the following expense during the periods presented:
			Three Months Ended					Nine Months Ended
			September 30,					September 30,
			2013			2012		2013		2012
	Phantom units		$	1,092		$	939	$	2,891	$	4,196
	Director deferred and common units			156			147		465		447
			$	1,248		$	1,086	$	3,356	$	4,643

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies	9	Commitments and Contingencies
	Legal
	We are involved, from time to time, in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, our management believes that these claims will not have a material adverse effect on our financial position or results of operations.
	Environmental Compliance
	As of September 30, 2013 and December 31, 2012, our environmental liabilities were $0.8 million and $0.9 million, which represent our best estimate of the liabilities as of those dates related to our Coal and Natural Resource Management, Eastern Midstream and Midcontinent Midstream businesses. We have reclamation bonding requirements with respect to certain unleased and inactive properties. Given the uncertainty of when a reclamation area will meet regulatory standards, a change in this estimate could occur in the future.
	Customer Credit Risk
	We are exposed to the credit risk of our customers and lessees. For the nine months ended September 30, 2013, 43% of our total consolidated revenues and 41% of our September 30, 2013 consolidated accounts receivable resulted from six of our natural gas midstream customers. Within the Eastern Midstream segment for the nine months ended September 30, 2013, 56% of the segment’s revenues and 53% of the September 30, 2013 accounts receivable for the segment resulted from three customers. Within the Midcontinent Midstream segment for the nine months ended September 30, 2013, 47% of the segment’s revenues and 39% of the September 30, 2013 accounts receivable for the segment resulted from three customers. These customer concentrations may impact our results of operations, either positively or negatively, in that these counterparties may be similarly affected by changes in economic or other conditions. We are not aware of any financial difficulties experienced by these customers.
	Coal royalties from lessees are impacted by several factors that we generally cannot control. The number of tons mined is determined by an operator’s mining efficiency, labor availability, geologic conditions, access to capital, ability to market coal and ability to arrange reliable transportation to the end-user. Legislation or regulations have been or may be adopted which may have a significant impact on the mining operations of our lessees or their customers’ ability to use coal and which may require us, our lessees or lessees’ customers to change operations significantly or incur substantial costs.
	As of September 30, 2013, we had recorded a $0.3 million allowance for doubtful accounts in the Midcontinent Midstream segment.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions	10	Related Party Transactions
	We own a member interest in Aqua – PVR Water Services LLC (“Aqua – PVR”), which operates a pipeline system to supply fresh water to natural gas producers drilling in the Marcellus Shale in Pennsylvania. Related to the Aqua – PVR joint venture we have executed agreements where PVR charges the joint venture fees for construction management services and accounting management services. The construction management services fee is 10% of the construction costs of a project managed by PVR. These fees began in 2012 and are not presumed to be carried out on an arm’s-length basis. The construction fees are invoiced once the project is complete, and the other services are invoiced once incurred or quarterly. The table below discloses the related party transactions for the period presented. The statements of operations amounts are net of eliminations.
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2013		2012		2013		2012
	Consolidated Statements of Operations:
	Other income		$	217	$	803	$	481	$	2,043
	General and administrative		$	5	$	3	$	16	$	19
			September 30,		December 31,
			2013		2012
	Consolidated Balance Sheets:
	Accounts receivable		$	5,001	$	6,442
	Accounts payable		$	—	$	172

Segment_Information

Segment Information	9 Months Ended
	Sep. 30, 2013
Segment Information	11	Segment Information
	Our reportable segments are as follows:
		•		Eastern Midstream — Our Eastern Midstream segment is engaged in providing natural gas gathering, transportation and other related services in Pennsylvania, Ohio and West Virginia. In addition, we own member interests in a joint venture that transports fresh water to natural gas producers.
		•		Midcontinent Midstream — Our Midcontinent Midstream segment is engaged in providing natural gas gathering, processing and other related services. These processing and gathering systems are located primarily in Oklahoma and Texas.
		•		Coal and Natural Resource Management — Our Coal and Natural Resource Management segment primarily involves the management and leasing of coal properties and the subsequent collection of royalties. We also earn revenues from other land management activities, such as selling standing timber, leasing coal-related infrastructure facilities and collecting oil and gas royalties.
			Eastern		Midcontinent			Coal and		Consolidated
			Midstream		Midstream			Natural
								Resource
								Management
	Three Months Ended September 30, 2013
	Revenues		$	51,719	$	211,879		$	25,366	$	288,964
	Cost of midstream gas purchased			—		163,824			—		163,824
	Operating costs and expenses			8,204		16,650			6,054		30,908
	Depreciation, depletion & amortization			25,355		15,719			6,059		47,133
	Operating income		$	18,160	$	15,686		$	13,253	$	47,099
	Interest expense										(28,358	)
	Derivatives										(965	)
	Other										112
	Net income									$	17,888
	Additions to property and equipment		$	65,701	$	19,049		$	4	$	84,754
	Three Months Ended September 30, 2012
	Revenues		$	26,800	$	207,522		$	34,525	$	268,847
	Cost of midstream gas purchased			—		147,246			—		147,246
	Operating costs and expenses			5,360		15,990			7,768		29,118
	Depreciation, depletion & amortization			11,867		11,913			8,212		31,992
	Operating income		$	9,573	$	32,373		$	18,545	$	60,491
	Interest expense										(20,288	)
	Derivatives										(1,524	)
	Other										104
	Net income									$	38,783
	Additions to property and equipment		$	146,726	$	25,919		$	23	$	172,668
	Nine Months Ended September 30, 2013
	Revenues		$	141,054	$	599,889		$	84,897	$	825,840
	Cost of midstream gas purchased			—		489,106			—		489,106
	Operating costs and expenses			21,758		48,748			19,879		90,385
	Depreciation, depletion & amortization			71,461		45,679			20,892		138,032
	Operating income		$	47,835	$	16,356		$	44,126	$	108,317
	Interest expense										(78,362	)
	Derivatives										(560	)
	Other										1,238
	Net income									$	30,633
	Additions to property and equipment		$	284,688	$	59,320		$	2,429	$	346,437
	Nine Months Ended September 30, 2012
	Revenues		$	59,397	$	571,053		$	107,726	$	738,176
	Cost of midstream gas purchased			—		453,543			—		453,543
	Operating costs and expenses			10,337		48,217			23,550		82,104
	Acquisition related costs			14,049		—			—		14,049
	Impairments			—		124,845			—		124,845
	Depreciation, depletion & amortization			22,322		37,220			24,759		84,301
	Operating income (loss)		$	12,689	$	(92,772	)	$	59,417	$	(20,666	)
	Interest expense										(45,616	)
	Derivatives										2,201
	Other										329
	Net loss									$	(63,752	)
	Additions to property and equipment		$	1,095,723	$	101,894		$	988	$	1,198,605
			Total assets
			September 30, 2013		December 31, 2012
	Eastern Midstream		$	1,855,783	$	1,677,846
	Midcontinent Midstream			589,420		640,437
	Coal and Natural Resource Management			655,077		680,426
	Totals		$	3,100,280	$	2,998,709

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events	12	Subsequent Events
	On October 9, 2013, PVR, together with PVR GP, LLC, a Delaware limited liability company and PVR’s general partner (the “General Partner”) entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Regency Energy Partners LP, a Delaware limited partnership (“Regency”), RVP LLC, a Delaware limited liability company and a wholly owned subsidiary of Regency (“Merger Sub”) and Regency GP LP, a Delaware limited partnership and the general partner of Regency (“Regency GP”), pursuant to which PVR will merge with and into Merger Sub (the “Merger”), with PVR continuing its existence as the surviving entity of the merger. Upon the completion of the Merger, PVR will be a wholly-owned subsidiary of Regency. The board of directors of Regency’s managing general partner and the sole member of Merger Sub have unanimously approved the Merger Agreement, and the board of directors of PVR’s General Partner has unanimously approved and agreed to submit the Merger Agreement to a vote of the PVR unitholders and to recommend that the unitholders adopt the Merger Agreement.
	Under the terms of the Merger Agreement, holders of PVR common units and Class B Units will receive 1.020 common units of Regency for each PVR unit outstanding immediately prior to the effective time of the Merger. In addition, PVR unitholders will receive a one-time cash payment at closing of the Merger estimated to be approximately $40.0 million in the aggregate. The consideration to be received by PVR unitholders is valued at $28.68 per common unit based on Regency’s closing price as of October 9, 2013, representing a 25.7% premium to the closing price of PVR’s common units of $22.81 on October 9, 2013.
	The Merger Agreement is subject to customary closing conditions including, among other things, (i) approval of the Merger Agreement by PVR’s unitholders, (ii) receipt of applicable regulatory approvals, (iii) the effectiveness of a registration statement on Form S-4 with respect to the issuance of Regency common units to be issued in connection with the Merger, (iv) receipt of certain tax opinions, (v) approval for listing of the Regency common units to be issued in connection with the Merger on the New York Stock Exchange and (vi) conversion of the 10,346,257 Special Units outstanding as of the date of the Merger Agreement into an aggregate of 10,346,257 common units.
	On October 16, 2013, 0.6 million additional common units were purchased by the underwriter pursuant to the September 2013 equity offering and the related option to purchase additional units. See a discussion of the 2013 equity offering in Note. 7. The net proceeds of the option exercise will be approximately $13.6 million, after deducting estimated fees and expenses and underwriting discounts and commissions totaling approximately $0.2 million. The net proceeds will be used to repay a portion of the Revolver.
	In October 2013, the Board of Directors of PVR GP, LLC, the general partner of PVR, approved a plan to redeem up to $127.4 million of our 8.375% Senior Notes due in 2020 (the “Senior Notes”). This plan is revocable at our discretion until the trustee issues notification of a redemption to the holders of the Senior Notes. Using proceeds from borrowings under the Revolver, we expect to redeem the Senior Notes on December 1, 2013, resulting in a charge of approximately $14.0 million in the fourth quarter of 2013. The loss on extinguishment of debt would represent the difference between the reacquisition price on the portion of the Senior Notes redeemed, which includes any premium, and the net carrying amount of the Senior Notes.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Assets and Liabilities Measured at Fair Value on Recurring Basis	The following table summarizes the assets and liabilities measured at fair value on a recurring basis for our commodity-based derivative financial instruments:
					Fair Value Measurements at September 30, 2013, Using
	Description	Fair Value			Quoted Prices in		Significant Other			Significant
		Measurements at			Active Markets for		Observable Inputs			Unobservable
		September 30, 2013			Identical Assets		(Level 2)			Inputs (Level 3)
					(Level 1)
	Commodity derivative assets - current	$	229		$	—	$	229		$	—
	Commodity derivative liabilities - current		(691	)	$	—		(691	)	$	—
	Total	$	(462	)	$	—	$	(462	)	$	—

Derivative_Instruments_Tables

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Schedule of Positions for Commodities Related to Revenues	The following table sets forth our positions as of September 30, 2013 for commodities related to revenues:
		Average				Weighted Average				Fair Value at
		Volume				Swap Price				September 30,
		Per Day								2013
	Crude oil swap		(barrels	)			(per barrel	)
	Fourth quarter 2013		500			$	94.8			$	(309	)
	Natural gas swaps		(MMBtu	)			(per MMBtu	)
	Fourth quarter 2013		5,500			$	3.823				229
	Propane swap - OPIS Conway		(gallons	)			(per gallon	)
	Fourth quarter 2013		42,000			$	1.00875				(125	)
	Settlements to be paid in subsequent period										(257	)
Effects of Derivative Activities and Location of Gains and Losses on Statement of Income	The following table summarizes the effects of our derivative activities, as well as the location of gains (losses) on our Consolidated Statements of Operations for the periods presented:
		Location of gain (loss)		Three Months Ended								Nine Months Ended
		on derivatives recognized		September 30,								September 30,
		in statement of operations		2013				2012				2013			2012
	Derivatives not designated as hedging instruments:
	Commodity contracts	Derivatives		$	(965	)		$	(1,695	)		$	(560	)	$	1,879
	Interest rate contracts	Derivatives			—				171				—			322
	Total increase (decrease) in net income resulting from derivatives			$	(965	)		$	(1,524	)		$	(560	)	$	2,201
	Realized and unrealized derivative impact:
	Cash received (paid) for commodity and interest rate contract settlements	Derivatives		$	(123	)		$	(1,332	)		$	(98	)	$	(8,578	)
	Unrealized derivative gains (losses)	Derivatives			(842	)			(192	)			(462	)		10,779
	Total increase (decrease) in net income resulting from derivatives			$	(965	)		$	(1,524	)		$	(560	)	$	2,201
Summary of Fair Value of Derivative Instruments and Location of these Instruments on Consolidated Balance Sheets	The following table summarizes the fair value of our derivative instruments, as well as the locations of these instruments on our Consolidated Balance Sheets for the new commodity hedges entered into during the period presented:
				Fair Values as of
				September 30, 2013
		Balance Sheet Location		Derivative				Derivative
				Assets				Liabilities
	Derivatives not designated as hedging instruments:
	Commodity contracts	Derivative assets/liabilities - current			229				691
	Total derivatives not designated as hedging instruments			$	229			$	691
	Total fair value of derivative instruments			$	229			$	691

Equity_Investments_Tables

Equity Investments (Tables)	9 Months Ended
	Sep. 30, 2013
Summary of Financial Information of Unconsolidated Equity Investments	Summarized financial information of unconsolidated equity investments is as follows for the periods presented:
		August 31,		November 30,
		2013		2012
	Current assets	$	22,682	$	55,351
	Noncurrent assets	$	111,288	$	273,158
	Current liabilities	$	15,749	$	38,188
	Noncurrent liabilities	$	1,720	$	3,933
		Nine Months Ended August 31,
		2013		2012
	Revenues	$	34,447	$	42,772
	Expenses	$	30,107	$	29,190
	Net income	$	4,340	$	13,582

Partners_Capital_and_Distribut1

Partners' Capital and Distributions (Tables)	9 Months Ended
	Sep. 30, 2013
Reconciliation of Net Income (Loss) and Weighted Average Units Used in Computing Basic and Diluted Net Income (Loss) Per Limited Partner Unit	The following table reconciles net income (loss) and weighted average common units used in computing basic and diluted net income (loss) per common unit (in thousands, except per unit data):
			Three Months Ended						Nine Months Ended
			September 30,						September 30,
			2013			2012			2013			2012
	Net income (loss)		$	17,888		$	38,783		$	30,633		$	(63,752	)
	Less:
	Distributions to participating securities			(13,124	)		(11,814	)		(38,577	)		(17,534	)
	Recognition of beneficial conversion feature (1)			(20,106	)		(17,120	)		(58,881	)		(28,174	)
	Participating securities’ allocable share of undistributed net loss			6,621			3,969			21,898			14,109
	Net income (loss) allocable to common units, basic and diluted		$	(8,721	)	$	13,818		$	(44,927	)	$	(95,351	)
	Weighted average number of common units outstanding, basic and diluted			96,983			88,366			96,283			83,834
	Net income (loss) per common unit, basic and diluted		$	(0.09	)	$	0.16		$	(0.47	)	$	(1.14	)
	-1	Special Units and Class B Units were issued at prices below the market price of the common units into which they are convertible. The aggregate discount of $139.2 million represents a beneficial conversion feature which is considered a non-cash distribution that will be distributed ratably using the effective yield method over the period the Special Units and Class B Units are outstanding. The impact of the beneficial conversion feature is included as distributed income to Class B Units and Special Units with a corresponding reduction in net income allocable to common units in the calculation of net income loss per common unit for the three and nine months ended September 30, 2013 and 2012.
Weighted Average Number of Each Class of Participating Securities Excluded from Diluted Net Income (Loss) Per Common Unit	The following table presents the weighted average number of each class of participating securities that were excluded from the diluted net income (loss) per common unit calculation because the inclusion of these units would have had an antidilutive effect:
			Three Months Ended						Nine Months Ended
			September 30,						September 30,
			2013			2012			2013			2012
	Special units			10,346			10,346			10,346			5,173
	Class B units			23,621			21,620			23,129			10,770
	Phantom units			78			73			70			51
				34,045			32,039			33,545			15,994

UnitBased_Compensation_Tables

Unit-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2013
Schedule of Expected Life of Phantom Units	We base the risk-free interest rate on the U.S. Treasury rate for the week of the grant having a term equal to the expected life of the phantom units, continuously compounded.
		2013
	Expected volatility		28.2	%
	Expected life		2.7 years
	Risk-free interest rate		0.31	%
Components of Recognized Expenses	In connection with the normal three-year vesting of phantom units, as well as common unit and deferred common unit awards, we recognized the following expense during the periods presented:
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Phantom units	$	1,092		$	939	$	2,891	$	4,196
	Director deferred and common units		156			147		465		447
		$	1,248		$	1,086	$	3,356	$	4,643

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions - Statement of Operations
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2013		2012		2013		2012
	Consolidated Statements of Operations:
	Other income	$	217	$	803	$	481	$	2,043
	General and administrative	$	5	$	3	$	16	$	19
Related Party Transactions - Balance Sheets
		September 30,		December 31,
		2013		2012
	Consolidated Balance Sheets:
	Accounts receivable	$	5,001	$	6,442
	Accounts payable	$	—	$	172

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2013
Schedule of Segments Financial Information
		Eastern		Midcontinent			Coal and		Consolidated
		Midstream		Midstream			Natural
							Resource
							Management
	Three Months Ended September 30, 2013
	Revenues	$	51,719	$	211,879		$	25,366	$	288,964
	Cost of midstream gas purchased		—		163,824			—		163,824
	Operating costs and expenses		8,204		16,650			6,054		30,908
	Depreciation, depletion & amortization		25,355		15,719			6,059		47,133
	Operating income	$	18,160	$	15,686		$	13,253	$	47,099
	Interest expense									(28,358	)
	Derivatives									(965	)
	Other									112
	Net income								$	17,888
	Additions to property and equipment	$	65,701	$	19,049		$	4	$	84,754
	Three Months Ended September 30, 2012
	Revenues	$	26,800	$	207,522		$	34,525	$	268,847
	Cost of midstream gas purchased		—		147,246			—		147,246
	Operating costs and expenses		5,360		15,990			7,768		29,118
	Depreciation, depletion & amortization		11,867		11,913			8,212		31,992
	Operating income	$	9,573	$	32,373		$	18,545	$	60,491
	Interest expense									(20,288	)
	Derivatives									(1,524	)
	Other									104
	Net income								$	38,783
	Additions to property and equipment	$	146,726	$	25,919		$	23	$	172,668
	Nine Months Ended September 30, 2013
	Revenues	$	141,054	$	599,889		$	84,897	$	825,840
	Cost of midstream gas purchased		—		489,106			—		489,106
	Operating costs and expenses		21,758		48,748			19,879		90,385
	Depreciation, depletion & amortization		71,461		45,679			20,892		138,032
	Operating income	$	47,835	$	16,356		$	44,126	$	108,317
	Interest expense									(78,362	)
	Derivatives									(560	)
	Other									1,238
	Net income								$	30,633
	Additions to property and equipment	$	284,688	$	59,320		$	2,429	$	346,437
	Nine Months Ended September 30, 2012
	Revenues	$	59,397	$	571,053		$	107,726	$	738,176
	Cost of midstream gas purchased		—		453,543			—		453,543
	Operating costs and expenses		10,337		48,217			23,550		82,104
	Acquisition related costs		14,049		—			—		14,049
	Impairments		—		124,845			—		124,845
	Depreciation, depletion & amortization		22,322		37,220			24,759		84,301
	Operating income (loss)	$	12,689	$	(92,772	)	$	59,417	$	(20,666	)
	Interest expense									(45,616	)
	Derivatives									2,201
	Other									329
	Net loss								$	(63,752	)
	Additions to property and equipment	$	1,095,723	$	101,894		$	988	$	1,198,605
		Total assets
		September 30, 2013		December 31, 2012
	Eastern Midstream	$	1,855,783	$	1,677,846
	Midcontinent Midstream		589,420		640,437
	Coal and Natural Resource Management		655,077		680,426
	Totals	$	3,100,280	$	2,998,709

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2013
	Segment
Organization and Nature of Operations [Line Items]
Number of operating business segments	3

Divestitures_Additional_Inform

Divestitures - Additional Information (Detail) (USD $)	3 Months Ended		9 Months Ended		1 Months Ended
	Sep. 30, 2013	Mar. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Aug. 19, 2013
					Thunder Creek Gas Services LLC
Property, Plant and Equipment [Line Items]
Assets held for sale				$11,450,000
Progress payments on a Midcontinent Midstream plant sold		12,000,000
Gain on sales of project		500,000
Membership interest ownership percentage					25.00%
Equity investments	57,863,000		57,863,000	97,553,000	44,300,000
Proceeds from sale of equity investment					58,600,000
Gain from sale of equity investment	$14,302,000		$14,302,000		$14,300,000

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Detail) (USD $)	Sep. 30, 2013
In Billions, unless otherwise specified
Fair Value Measurements [Line Items]
Fair value of fixed-rate debt	$1.30

Assets_and_Liabilities_Measure

Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of current assets	$229
Fair value of current liabilities	-691
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	-462
Fair Value, Measurements, Recurring | Commodity Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of current assets	229
Fair value of current liabilities	-691
Fair Value, Measurements, Recurring | Fair Value, Inputs, Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	-462
Fair Value, Measurements, Recurring | Fair Value, Inputs, Level 2 | Commodity Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of current assets	229
Fair value of current liabilities	($691)

Schedule_of_Positions_for_Comm

Schedule of Positions for Commodities Related to Natural Gas Midstream Revenues and Cost of Midstream Gas Purchased (Detail) (USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Payable In Subsequent Period
Derivative [Line Items]
Fair Value	($257)
Crude Oil Swap | Fourth Quarter 2013
Derivative [Line Items]
Average Volume Per Day	500
Weighted Average Swap Price	94.8
Fair Value	-309
Natural Gas Swaps | Fourth Quarter 2013
Derivative [Line Items]
Average Volume Per Day	5,500
Weighted Average Swap Price	3.823
Fair Value	229
Propane swap - OPIS Conway | Fourth Quarter 2013
Derivative [Line Items]
Average Volume Per Day	42,000
Weighted Average Swap Price	1.00875
Fair Value	($125)

Derivative_Instruments_Additio

Derivative Instruments - Additional Information (Detail) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2012
Derivative [Line Items]
Derivative gain in AOCI recognized	$0.20
Net hedging losses in the derivatives recognized	0.5
Derivative liabilities		$0.20

Effects_of_Derivative_Activiti

Effects of Derivative Activities and Location of Gains and Losses on Statement of Operations (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative [Line Items]
Gain (loss) on derivatives recognized in income	($965)	($1,524)	($560)	$2,201
Not Designated as Hedging Instrument
Derivative [Line Items]
Gain (loss) on derivatives recognized in income	-965	-1,524	-560	2,201
Not Designated as Hedging Instrument | Derivatives
Derivative [Line Items]
Cash received (paid) for commodity and interest rate contract settlements	-123	-1,332	-98	-8,578
Unrealized derivative gains (losses)	-842	-192	-462	10,779
Not Designated as Hedging Instrument | Commodity Contract | Derivatives
Derivative [Line Items]
Gain (loss) on derivatives recognized in income	-965	-1,695	-560	1,879
Not Designated as Hedging Instrument | Interest Rate Contract | Derivatives
Derivative [Line Items]
Gain (loss) on derivatives recognized in income		$171		$322

Summary_of_Fair_Value_of_Deriv

Summary of Fair Value of Derivative Instruments and Location of these Instruments on Consolidated Balance Sheets (Detail) (USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]
Derivative assets, current	$229
Derivative liabilities, current	691
Total fair value of derivative instruments, assets	229
Total fair value of derivative instruments, liabilities	691
Not Designated as Hedging Instrument
Derivative [Line Items]
Derivative assets	229
Derivative liabilities	691
Not Designated as Hedging Instrument | Commodity Contract
Derivative [Line Items]
Derivative assets, current	229
Derivative liabilities, current	$691

Equity_Investments_Additional_

Equity Investments - Additional Information (Detail) (USD $)	3 Months Ended	9 Months Ended			1 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Aug. 19, 2013
					Thunder Creek Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Equity earnings		$900,000	$3,800,000
Distributions		6,500,000	4,000,000
Membership interest ownership percentage					25.00%
Equity investments	57,863,000	57,863,000		97,553,000	44,300,000
Proceeds from sale of equity investment					58,600,000
Gain from sale of equity investment	$14,302,000	$14,302,000			$14,300,000

Summary_of_Financial_Informati

Summary of Financial Information of Unconsolidated Equity Investments (Detail) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Aug. 31, 2013	Aug. 31, 2012	Nov. 30, 2012
Schedule of Equity Method Investments [Line Items]
Current assets	$22,682		$55,351
Noncurrent assets	111,288		273,158
Current liabilities	15,749		38,188
Noncurrent liabilities	1,720		3,933
Revenues	34,447	42,772
Expenses	30,107	29,190
Net income	$4,340	$13,582

LongTerm_Debt_Additional_Infor

Long-Term Debt - Additional Information (Detail) (USD $)	1 Months Ended	3 Months Ended		9 Months Ended
	31-May-13	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Feb. 21, 2013	Feb. 21, 2013
							Senior notes 8.250%	Senior notes 8.375%	Fiscal period ending September 30, 2013 through the fiscal period ending December 31, 2013	Fiscal period ending March 31, 2014, and for each fiscal period thereafter
									Maximum	Maximum
Debt Instrument [Line Items]
Leverage Ratio									550.00%	525.00%
Minimum adjusted EBITDA allowed for material capital projects				$10,000,000
Indebtedness outstanding		332,500,000		332,500,000
Letters of credit		10,400,000		10,400,000
Remaining borrowing capacity		657,100,000		657,100,000
Weighted average interest rate on borrowings				3.40%
Senior notes, face amount	400,000,000
Debt interest rate	6.50%						8.25%	8.38%
Senior notes, due date	15-May-21
Net proceeds from issuance of senior notes	391,000,000			400,000,000	600,000,000
Payment for fees and expenses	9,000,000	158,000	617,000	9,695,000	19,206,000
Senior notes		$1,300,000,000		$1,300,000,000		$900,000,000	$300,000,000	$600,000,000
Senior notes, due date							2018-04	2020-06
Percentage of finance subsidiaries owned		100.00%		100.00%
Percentage of subsidiary guarantors owned		100.00%		100.00%

Partners_Capital_and_Distribut2

Partners' Capital and Distributions - Additional Information (Detail) (USD $)	1 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2013	Aug. 31, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Units outstanding	101,200,000		101,200,000		101,200,000
Limited partner's interest	5,500,000
Net proceeds from issuance of partner's capital	$124,500,000
Cost associated with issuance of partner's capital	2,000,000
Common units offering price		150,000,000
Percentage of distributed of available cash			100.00%
Maximum period of cash distribution to limited partners			45 days
Cash distributions during the period			52,781,000	46,833,000	158,302,000	128,516,000
Maximum
Sales of common units shall not exceed gross sales price per common unit, percentage		2.00%
Scenario, Forecast
Quarterly distribution to common unit holders, distribution date			13-Nov-13
Scenario, Forecast | Unit Distribution
Quarterly distribution to common unit holders, distribution date			13-Nov-13
Quarterly payment of distribution per unit			$0.55
Quarterly distribution to common unitholders, record date			6-Nov-13
Special Units
Business acquisition equity issuance shares			10,300,000
Amount that would have been paid if special units entitled and accrue cash distribution			5,700,000
Conversion date of Special Units to common units			7-Nov-13
Class B Units
Business acquisition equity issuance shares			23,800,000
Amount that would have been paid if special units entitled and accrue cash distribution			$13,100,000
Class B Units | Scenario, Forecast
Unit issued	525,624		525,624		525,624

Reconciliation_of_Net_Income_L

Reconciliation of Net Income (Loss) and Weighted Average Units Used in Computing Basic and Diluted Net Income (Loss) Per Limited Partner Unit (Detail) (USD $)	3 Months Ended				9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Net income (loss)	$17,888		$38,783		$30,633		($63,752)
Distributions to participating securities	-13,124		-11,814		-38,577		-17,534
Recognition of beneficial conversion feature	-20,106	[1]	-17,120	[1]	-58,881	[1]	-28,174	[1]
Participating securities' allocable share of undistributed net loss	6,621		3,969		21,898		14,109
Net income (loss) allocable to common units, basic and diluted	($8,721)		$13,818		($44,927)		($95,351)
Weighted average number of common units outstanding, basic and diluted	96,983		88,366		96,283		83,834
Net income (loss) per common unit, basic and diluted	($0.09)		$0.16		($0.47)		($1.14)
[1]	Special Units and Class B Units were issued at prices below the market price of the common units into which they are convertible. The aggregate discount of $139.2 million represents a beneficial conversion feature which is considered a non-cash distribution that will be distributed ratably using the effective yield method over the period the Special Units and Class B Units are outstanding. The impact of the beneficial conversion feature is included as distributed income to Class B Units and Special Units with a corresponding reduction in net income allocable to common units in the calculation of net income loss per common unit for the three and nine months ended September 30, 2013 and 2012

Reconciliation_of_Net_Income_L1

Reconciliation of Net Income (Loss) and Weighted Average Units Used in Computing Basic and Diluted Net Income (Loss) Per Limited Partner Unit (Parenthetical) (Detail) (USD $)	Jun. 30, 2013
In Millions, unless otherwise specified
Non-cash distribution	$139.20

Weighted_Average_Number_of_Eac

Weighted Average Number of Each Class of Participating Securities Excluded from Diluted Net Income (Loss) Per Common Unit (Detail)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Weighted average units excluded from diluted net income per common unit calculation	34,045	32,039	33,545	15,994
Special Units
Weighted average units excluded from diluted net income per common unit calculation	10,346	10,346	10,346	5,173
Class B Units
Weighted average units excluded from diluted net income per common unit calculation	23,621	21,620	23,129	10,770
Phantom Units
Weighted average units excluded from diluted net income per common unit calculation	78	73	70	51

UnitBased_Compensation_Additio

Unit-Based Compensation - Additional Information (Detail) (USD $)	9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013
Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units granted at a weighted average grant-date fair value	288
Amount of common units granted at a weighted average grant-date fair value	$23.19
Time Based Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units granted at a weighted average grant-date fair value	186
Performance Based Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units granted at a weighted average grant-date fair value	102
Amount of common units granted at a weighted average grant-date fair value	$17.60
Performance Based Phantom Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units vested percentage	0.00%
Performance Based Phantom Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units vested percentage	200.00%

Schedule_of_Expected_Life_of_P

Schedule of Expected Life of Phantom Units (Detail)	9 Months Ended
	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected volatility	28.20%
Expected life	2 years 8 months 12 days
Risk-free interest rate	0.31%

Components_of_Recognized_Expen

Components of Recognized Expenses (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	$1,248	$1,086	$3,356	$4,643
Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	1,092	939	2,891	4,196
Director deferred and common units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	$156	$147	$465	$447

Commitments_and_Contingencies_

Commitments and Contingencies - Additional Information (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
In Millions, unless otherwise specified			Consolidated revenues	Consolidated accounts receivable	Midcontinent Midstream Segment	Total Three Customer For Natural Gas Eastern Midstream Segment	Total Three Customer For Natural Gas Eastern Midstream Segment	Total Three Customers For Natural Gas Mid continent Midstream Segment	Total Three Customers For Natural Gas Mid continent Midstream Segment
						Consolidated revenues	Consolidated accounts receivable	Consolidated revenues	Consolidated accounts receivable
Product Liability Contingency [Line Items]
Environmental liabilities	$0.80	$0.90
Concentration risk percentage			43.00%	41.00%		56.00%	53.00%	47.00%	39.00%
Allowance for doubtful accounts					$0.30

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (Aqua PVR Water Services LLC)	Sep. 30, 2013
Aqua PVR Water Services LLC
Related Party Transaction [Line Items]
Construction management services fee as percentage of construction costs of project	10.00%

Related_Party_Transactions_Det

Related Party Transactions (Detail) (Aqua PVR Water Services LLC, USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Aqua PVR Water Services LLC
Related Party Transaction [Line Items]
Other income	$217	$803	$481	$2,043
General and administrative	5	3	16	19
Accounts receivable	5,001		5,001		6,442
Accounts payable					$172

Schedule_of_Segments_Financial

Schedule of Segments Financial Information (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenues	$288,964	$268,847	$825,840	$738,176
Cost of midstream gas purchased	163,824	147,246	489,106	453,543
Operating costs and expenses	30,908	29,118	90,385	82,104
Acquisition related costs				14,049
Impairments				124,845
Depreciation, depletion & amortization	47,133	31,992	138,032	84,301
Operating income (loss)	47,099	60,491	108,317	-20,666
Interest expense	-28,358	-20,288	-78,362	-45,616
Derivatives	-965	-1,524	-560	2,201
Other	112	104	1,238	329
Net income (loss)	17,888	38,783	30,633	-63,752
Additions to property and equipment	84,754	172,668	346,437	1,198,605
Total assets	3,100,280		3,100,280		2,998,709
Operating Segments | Eastern Midstream Segment
Segment Reporting Information [Line Items]
Revenues	51,719	26,800	141,054	59,397
Operating costs and expenses	8,204	5,360	21,758	10,337
Acquisition related costs				14,049
Depreciation, depletion & amortization	25,355	11,867	71,461	22,322
Operating income (loss)	18,160	9,573	47,835	12,689
Additions to property and equipment	65,701	146,726	284,688	1,095,723
Total assets	1,855,783		1,855,783		1,677,846
Operating Segments | Midcontinent Midstream Segment
Segment Reporting Information [Line Items]
Revenues	211,879	207,522	599,889	571,053
Cost of midstream gas purchased	163,824	147,246	489,106	453,543
Operating costs and expenses	16,650	15,990	48,748	48,217
Impairments				124,845
Depreciation, depletion & amortization	15,719	11,913	45,679	37,220
Operating income (loss)	15,686	32,373	16,356	-92,772
Additions to property and equipment	19,049	25,919	59,320	101,894
Total assets	589,420		589,420		640,437
Operating Segments | Coal And Natural Resource Management Segment
Segment Reporting Information [Line Items]
Revenues	25,366	34,525	84,897	107,726
Operating costs and expenses	6,054	7,768	19,879	23,550
Depreciation, depletion & amortization	6,059	8,212	20,892	24,759
Operating income (loss)	13,253	18,545	44,126	59,417
Additions to property and equipment	4	23	2,429	988
Total assets	$655,077		$655,077		$680,426

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	1 Months Ended			9 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	31-May-13	Sep. 30, 2013	Sep. 30, 2013	Oct. 16, 2013	Oct. 09, 2013	Oct. 29, 2013	Oct. 29, 2013	Oct. 09, 2013	Oct. 09, 2013	Oct. 09, 2013
			Senior notes 8.375%	Senior notes 8.375%	Subsequent Event	Subsequent Event	Subsequent Event	Subsequent Event	Subsequent Event	Subsequent Event	Subsequent Event
				Fourth quarter of 2013			Senior notes 8.375%	Senior notes 8.375%	Regency Energy Partners LP	Regency Energy Partners LP	Regency Energy Partners LP
								Maximum		Special Units	Common Units
Merger, Acquisition, Integration and Transitional Related Costs and Other Charges [Line Items]
Number of common units of Regency received by common units and Class B units of RVR									1.02
Cash entitlement at closure of merger									$40
Consideration received by unit holders									$28.68
Merger consideration percentage of premium on closing price									25.70%
Closing price of PVR's common units						$22.81
Merger agreement, shares of units exchanged										10,346,257	10,346,257
Additional common units purchased by underwriter	5,500,000				600,000
Net proceeds from options exercise	124.5				13.6
Cost associated with option exercise	2				0.2
Notes approved for redemption								127.4
Senior notes, interest rate		6.50%	8.38%				8.38%
Senior notes, maturity year							2020
Charge on extinguishment of debt				$14
Note redemption date			1-Dec-13