Exhibit 99.1

Penn Virginia Resource Partners, L.P.   Five Radnor Corporate Center, Suite 500, 100 Matsonford Road, Radnor, PA 19087

FOR IMMEDIATE RELEASE

Contact:	Stephen R. Milbourne
	Director - Investor Relations
	Phone: 610-975-8204
	E-Mail: invest@pvrpartners.com

PVR PARTNERS ANNOUNCES SECOND QUARTER RESULTS

AND INCREASES QUARTERLY DISTRIBUTION

RADNOR, PA – July 25, 2012 . . . Penn Virginia Resource Partners, L.P. (NYSE: PVR) (“PVR”) today reported financial and operational results for the three months ended June 30, 2012. In addition, PVR announced an increase in its quarterly distribution to $0.53 per unit.

Second Quarter Results

Second quarter 2012 highlights and results, with comparisons to second quarter 2011 results, included the following:

• Adjusted EBITDA of $57.0 million as compared to $64.8 million.

• Distributable cash flow (“DCF”) of $26.1 million as compared to $34.1 million.

• Adjusted net income of $9.6 million as compared to $23.0 million.

Adjusted EBITDA, distributable cash flow, and adjusted net income are not Generally Accepted Accounting Principles (“GAAP”) measures. Definitions and reconciliations of these non-GAAP measures to GAAP reporting measures appear in the financial tables which follow.

Quarterly Distribution

The Board of Directors of Penn Virginia Resource GP, LLC, the general partner of PVR, declared a quarterly distribution of $0.53 per unit payable in cash on August 14, 2012 to common unitholders of record at the close of business on August 6, 2012. This distribution equates to an annualized rate of $2.12 per unit, and represents a 1.9% increase over the prior quarter distribution and an 8.2% increase over the second quarter of 2011.

Management Comment

“We closed the previously announced acquisition of Chief Gathering LLC on May 17, 2012, and with the addition of these assets, we have begun to report separate results for the Midcontinent and Eastern segments of the midstream business. We believe this change will enhance the understanding of our business segments,” said Bill Shea, President and CEO of PVR’s general partner.

“Our second quarter results were negatively impacted by a very challenging coal market, low NGL prices and the migration to lower-margin fee-based contracts in the Midcontinent segment,” continued Mr. Shea. “However, the growth of our midstream business has continued in the second quarter with the closing of the Chief Gathering acquisition, the commencement of construction on Phase III and the Canton Lateral on our Lycoming County, Pennsylvania gas trunkline and water line, and completion of

PVR Announces Second Quarter 2012 Results Page 2

the second 60 million cubic feet per day expansion of our Antelope Hills facility. Phase III and the Canton Lateral are expected to be in service in the fourth quarter to gather gas for an affiliate of Southwestern Energy Company and a subsidiary of Royal Dutch Shell. The new Wyoming County, Pennsylvania gas trunkline, acquired in the Chief acquisition, is also expected to be operational in the fourth quarter, servicing affiliates of Chief Oil & Gas LLC and Chesapeake Energy Corporation, among others. The completion of the Antelope Hills expansion enables PVR to process all of its volumes in the Panhandle region, as well as additional third-party volumes.

“Based on our confidence in the expected cash flows from these and other attractive growth midstream projects, we have increased our quarterly distribution to $0.53 per unit,” concluded Mr. Shea.

Eastern Midstream Segment

The eastern natural gas midstream segment reported second quarter 2012 results, with comparisons to second quarter 2011 results, as follows:

• Adjusted EBITDA of $17.7 million as compared to $5.2 million, primarily due to the continued development of internal growth projects and the acquisition of Chief Gathering LLC.

• Quarterly natural gas midstream system average throughput volumes of 344 million cubic feet per day (“MMcfd”), as compared to 38 MMcfd. The volume growth reflects the expansion of business on PVR’s Lycoming and Wyoming systems, as well as the acquisition of Chief Gathering.

Midcontinent Midstream Segment

The midcontinent natural gas midstream segment reported second quarter 2012 results, with comparisons to second quarter 2011 results, as follows:

• Adjusted EBITDA of $12.7 million as compared to $17.4 million, primarily due to low NGL prices and the migration to lower-margin fee-based contracts.

• Quarterly natural gas midstream system average throughput volumes of 453 MMcfd, as compared to 422 MMcfd.

Coal and Natural Resource Management Segment

The coal and natural resource management segment reported second quarter 2012 results, with comparisons to second quarter 2011 results, as follows:

• Adjusted EBITDA of $26.7 million as compared to $42.3 million, primarily due to decreased coal production and pricing.

• Coal royalty tons of 7.8 million tons, as compared to 10.1 million tons.

• Coal royalties revenue of $29.2 million, or $3.76 per ton, as compared to $44.6 million, or $4.40 per ton.

Capital Investment and Resources

We invested approximately $129.0 million on internal growth projects during the second quarter of 2012, including $106.9 million in the Eastern Midstream Segment.

PVR Announces Second Quarter 2012 Results Page 3

As of June 30, 2012, we had borrowings of $432.0 million under our $1.0 billion revolving credit facility with remaining borrowing capacity thereunder of $560.1 million.

Financial Guidance for 2012 and 2013

Current guidance for full year 2012 results has been updated to reflect the acquisition of the Chief Gathering business, the sale of the Crossroads system, the Lycoming Phase III expansion and other recently announced capital investments to support additional agreements with natural gas producers, revised assumptions for the impact of lower commodity prices and lower expected coal production. PVR now anticipates full year 2012 Adjusted EBITDA in the range of $245-$260 million and full year 2012 distributable cash flow, net of maintenance and replacement capital, in the range of $120-$130 million.

We expect the challenges in the coal business to continue in 2013, as well as a slow recovery of NGL prices. We also expect that the completion of several internal growth projects in the Eastern Midstream segment will partially offset these issues. Accordingly, we are revising our 2013 guidance range of $480-$540 million for total Adjusted EBITDA to $415-$480 million.

PVR’s financial guidance is based on numerous assumptions about future events and conditions and, therefore, could vary materially from actual results. These estimates, including capital expenditure plans, are meant to provide guidance only and are subject to revision for acquisitions or operating environment changes. Adjusted EBITDA and distributable cash flow are non-GAAP measures; reconciliations of these non-GAAP measures to GAAP reporting measures appear in the financial tables which follow.

Second Quarter 2012 Financial and Operational Results Conference Call

A conference call and webcast, during which management will discuss second quarter 2012 financial and operational results, is scheduled for Wednesday, July 25, 2012 at 10:00 a.m. ET. Prepared remarks by William H. Shea, Jr., Chief Executive Officer, and other members of company management will be followed by a question and answer period. Interested parties may participate via phone by dialing 800-860-2442 (international 412-858-4600) five to ten minutes before the scheduled start of the conference call (reference the Penn Virginia Resource Partners call), or listen via webcast at http://www.videonewswire.com/event.asp?id=88074, or by logging on using the link posted on our website, www.pvrpartners.com. An on-demand replay of the webcast will be available on our website shortly after the conclusion of the call. A telephonic replay of the call will be available through August 2 by dialing 877-344-7529 (international: 412-317-0088) and using conference playback number 10015935.

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Penn Virginia Resource Partners, L.P. (NYSE: PVR) is a publicly traded limited partnership which owns and operates a network of natural gas midstream pipelines and processing plants, and owns and manages coal and natural resource properties. Our midstream assets, located principally in Texas, Oklahoma and Pennsylvania, provide gathering, transportation, compression, processing, dehydration and related services to natural gas producers. Our coal and natural resource properties, located in the Appalachian, Illinois and San Juan basins, are leased to experienced operators in exchange for royalty payments. More information about PVR is available on our website at www.pvrpartners.com.

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This release is intended to be a qualified notice under Treasury Regulation Section 1.1446-4(b). Brokers and nominees should treat one hundred percent (100.0%) of the Partnership’s distributions to non-U.S. investors as being attributable to income that is effectively connected with a United States trade or business. Accordingly, the Partnership’s distributions to non-U.S. investors are subject to federal income tax withholding at the highest applicable effective tax rate.

PVR Announces Second Quarter 2012 Results Page 4

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This press release includes “forward-looking statements” within the meaning of federal securities laws. All statements, other than statements of historical facts, included in this release that address activities, events or developments that the Partnership expects, believes or anticipates will or may occur in the future are forward-looking statements. These forward-looking statements rely on a number of assumptions concerning future events and are subject to a number of uncertainties, factors and risks, many of which are outside the Partnership’s ability to control or predict, which could cause results to differ materially from those expected by management. Such risks and uncertainties include, but are not limited to, regulatory, economic and market conditions, our ability to successfully complete the construction and development of Chief’s midstream systems, to integrate the business of Chief with ours and to realize the anticipated benefits from the acquisition of Chief, the timing and success of business development efforts and other uncertainties. Additional information concerning these and other factors can be found in our press releases and public periodic filings with the Securities and Exchange Commission, including our Annual Report on Form 10-K for the year ended December 31, 2011 and most recently filed Quarterly Reports on Form 10-Q. Readers should not place undue reliance on forward-looking statements, which reflect management’s views only as of the date hereof. We undertake no obligation to revise or update any forward-looking statements, or to make any other forward-looking statements, whether as a result of new information, future events or otherwise.

PENN VIRGINIA RESOURCE PARTNERS, L.P.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - unaudited

(in thousands, except per unit data)

	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Revenues
Natural gas	$	63,127		$	112,229		$	137,754		$	204,207
Natural gas liquids		102,130			136,048			219,924			244,890
Gathering and transportation		21,404			8,630			35,259			14,091
Coal royalties		29,231			44,578			62,390			83,569
Other		7,020			8,837			14,002			17,092
Total revenues		222,912			310,322			469,329			563,849
Expenses
Cost of gas purchased		140,833			219,278			306,297			389,533
Operating		14,040			14,242			29,943			27,315
General and administrative		10,999			11,975			23,043			22,945
Acquisition related costs		14,049			—			14,049			—
Impairments		—			—			124,845			—
Depreciation, depletion and amortization		28,456			21,650			52,309			42,894
Total expenses		208,377			267,145			550,486			482,687
Operating income (loss)		14,535			43,177			(81,157	)		81,162
Other income (expense)
Interest expense		(15,511	)		(12,428	)		(25,328	)		(23,278	)
Derivatives		8,676			4,782			3,725			(14,979	)
Interest income and other		109			127			225			264
Net income (loss)		7,809			35,658			(102,535	)		43,169
Net loss (income) attributable to noncontrolling interests		—			—			—			664
Net income (loss) attributable to Penn Virginia Resource Partners’, L.P.	$	7,809		$	35,658		$	(102,535	)	$	43,833
Basic earnings per common unit (1)	$	(0.07	)	$	0.50		$	(1.39	)	$	0.74
Diluted earnings per common unit (1)	$	(0.07	)	$	0.50		$	(1.39	)	$	0.74
Weighted average number of common units outstanding, basic		83,786			71,176			81,543			58,864
Weighted average number of common units outstanding, diluted		88,902			71,176			84,101			58,864

(1) On May 17, 2012, the Partnership issued Class B Units and Special Units at a price that was lower than the market price of the common units into which they are convertible. This discount is treated as a non-cash distribution for purposes of calculating earnings per unit and is reflected in the basic and diluted net income (loss) per unit using the effective yield method over the period the Class B Units and Special Units are expected to be outstanding.

Other data:
Daily throughput volumes (MMcfd) - Eastern Midstream	344	38	277	38
Daily throughput volumes (MMcfd) - Midcontinent Midstream	453	422	448	402
Coal royalty tons (in thousands)	7,776	10,125	15,881	20,022

PENN VIRGINIA RESOURCE PARTNERS, L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS - unaudited

(in thousands)

	June 30, 2012		December 31, 2011
Assets
Cash and cash equivalents	$	8,975	$	8,640
Accounts receivable		83,816		101,340
Assets held for sale		35,064		—
Other current assets		6,254		5,640
Total current assets		134,109		115,620
Property, plant and equipment, net		1,680,994		1,282,297
Other long-term assets		866,473		196,075
Total assets	$	2,681,576	$	1,593,992
Liabilities and Partners’ Capital
Accounts payable and accrued liabilities	$	138,487	$	124,082
Liabilities related to assets held for sale		3,260		—
Deferred income		3,851		3,416
Derivative liabilities		2,440		12,042
Total current liabilities		148,038		139,540
Other long-term liabilities		32,419		31,748
Senior notes 8.25%		900,000		300,000
Revolving credit facility		432,000		541,000
Partners’ capital		1,169,119		581,704
Total liabilities and partners’ capital	$	2,681,576	$	1,593,992

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited

(in thousands)

	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Cash flows from operating activities
Net income (loss)	$	7,809		$	35,658		$	(102,535	)	$	43,169
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization		28,456			21,650			52,309			42,894
Impairments		—			—			124,845			—
Commodity derivative contracts:
Total derivative losses included in net income		(8,676	)		(4,782	)		(3,725	)		14,979
Cash payments to settle derivatives for the period		(3,605	)		(7,920	)		(7,246	)		(12,778	)
Non-cash interest expense		1,579			2,655			2,628			3,695
Non-cash unit-based compensation		1,519			1,018			3,557			1,839
Equity earnings, net of distributions received		186			(1,343	)		(555	)		1,817
Other		(51	)		(635	)		(698	)		(782	)
Changes in operating assets and liabilities		(3,742	)		(8,758	)		62			(2,482	)
Net cash provided by operating activities		23,475			37,543			68,642			92,351
Cash flows from investing activities
Acquisitions, net of cash acquired		(850,747	)		(26,824	)		(850,943	)		(122,040	)
Additions to property, plant and equipment		(99,621	)		(37,345	)		(174,994	)		(74,796	)
Other		(4,770	)		1,204			(11,060	)		2,211
Net cash used in investing activities		(955,138	)		(62,965	)		(1,036,997	)		(194,625	)
Cash flows from financing activities
Net proceeds from equity offerings		577,962			—			577,962			—
Proceeds from issuance of senior notes		600,000			—			600,000			—
Distributions to partners		(41,265	)		(34,176	)		(81,683	)		(64,809	)
Proceeds from (repayments of) borrowings, net		(185,000	)		65,000			(109,000	)		172,000
Cash paid for debt issuance costs		(18,589	)		(3,675	)		(18,589	)		(3,675	)
Cash paid for merger		—			(5,600	)		—			(6,604	)
Net cash provided by financing activities		933,108			21,549			968,690			96,912
Net increase (decrease) in cash and cash equivalents		1,445			(3,873	)		335			(5,362	)
Cash and cash equivalents - beginning of period		7,530			14,475			8,640			15,964
Cash and cash equivalents - end of period	$	8,975		$	10,602		$	8,975		$	10,602

PENN VIRGINIA RESOURCE PARTNERS, L.P.

CERTAIN NON-GAAP FINANCIAL MEASURES - unaudited

(in thousands)

	Three Months Ended						Six Months Ended
	June 30,						June 30,						Guidance Range
	2012			2011			2012			2011			Full Year 2012
Reconciliation of Non-GAAP “Adjusted EBITDA” to GAAP “Net income (loss)”:
Segment Adjusted EBITDA (a):
Eastern Midstream	$	17,659		$	5,173		$	27,620		$	7,957		$	87,000		$	93,000
Midcontinent Midstream		12,684			17,392			25,007			37,039			58,000			62,000
Coal and Natural Resource Management		26,697			42,262			57,419			79,060			100,000			105,000
Total segment adjusted EBITDA	$	57,040		$	64,827		$	110,046		$	124,056		$	245,000		$	260,000
Adjustments to reconcile total segment Adjusted EBITDA to Net income (loss)
Depreciation, depletion and amortization		(28,456	)		(21,650	)		(52,309	)		(42,894	)
Impairments		—			—			(124,845	)		—
Acquisition related costs		(14,049	)		—			(14,049	)		—
Interest expense		(15,511	)		(12,428	)		(25,328	)		(23,278	)
Derivatives		8,676			4,782			3,725			(14,979	)
Other		109			127			225			264
Net income (loss)	$	7,809		$	35,658		$	(102,535	)	$	43,169
Reconciliation of GAAP “Net income (loss)” to Non-GAAP “Distributable cash flow”:
Net income (loss)	$	7,809		$	35,658		$	(102,535	)	$	43,169		$	(55,000	)	$	(60,000	)
Depreciation, depletion and amortization		28,456			21,650			52,309			42,894			123,000			132,000
Impairment		—			—			124,845			—			125,000			125,000
Gain on sale of assets		—			—			—			—			(33,000	)		(30,000	)
Acquisition related costs		14,049			—			14,049			—			14,000			14,000
Derivative contracts:
Derivative losses included in net income		(8,676	)		(4,782	)		(3,725	)		14,979			(1,000	)		5,000
Cash payments to settle derivatives for the period		(3,605	)		(7,920	)		(7,246	)		(12,778	)		(10,000	)		(13,000	)
Equity earnings from joint ventures, net of distributions		186			(1,343	)		(555	)		1,817			(1,000	)		1,000
Maintenance capital expenditures		(5,351	)		(2,469	)		(8,448	)		(5,648	)		(15,000	)		(17,000	)
Replacement capital expenditures		(6,725	)		(6,725	)		(13,450	)		(13,450	)		(27,000	)		(27,000	)
Distributable cash flow (b)	$	26,143		$	34,069		$	55,244		$	70,983		$	120,000		$	130,000
Distribution to Partners:
Total cash distribution paid during the period	$	41,265		$	34,176		$	81,683		$	64,809
Reconciliation of GAAP “Net income (loss)” to Non-GAAP “Net income as adjusted”:
Net income (loss)	$	7,809		$	35,658		$	(102,535	)	$	43,169
Impairments		—			—			124,845			—
Acquisition related costs		14,049			—			14,049			—
Adjustments for derivatives:
Derivative losses included in net income		(8,676	)		(4,782	)		(3,725	)		14,979
Cash payments to settle derivatives for the period		(3,605	)		(7,920	)		(7,246	)		(12,778	)
Net income, as adjusted (c)	$	9,577		$	22,956		$	25,388		$	45,370
													Guidance Range Full Year 2013
Reconciliation of Non-GAAP “Adjusted EBITDA” to GAAP “Operating income”:
Segment Adjusted EBITDA:
Eastern Midstream													$	250,000		$	275,000
Midcontinent Midstream														75,000			95,000
Coal and Natural Resource Management														90,000			110,000
Total segment adjusted EBITDA														415,000			480,000
Adjustments to reconcile total segment Adjusted EBITDA to Operating income
Depreciation, depletion and amortization														(174,000	)		(194,000	)
Operating income													$	241,000		$	286,000

(a) Adjusted EBITDA, or earnings before interest, tax and depreciation, depletion and amortization (“DD&A”), represents operating income plus DD&A, plus impairments, plus acquisition related costs. We believe EBITDA or a version of Adjusted EBITDA is commonly used by investors and professional research analysts in the valuation, comparison, rating and investment recommendations of companies in the natural gas midstream and coal industries. We use this information for comparative purposes within the industry. EBITDA is not a measure of financial performance under GAAP and should not be considered as a measure of liquidity or as an alternative to net income.

(b) Distributable cash flow represents net income plus DD&A, plus impairments, plus acquisition related costs, plus (minus) derivative losses (gains) included in net income, plus (minus) cash received (paid) for derivative settlements, minus equity earnings in joint ventures, plus cash distributions from joint ventures, minus maintenance capital expenditures, minus replacement capital expenditures. Distributable cash flow is also the quantitative standard used by investors and professional research analysts in the valuation, comparison, rating and investment recommendations of publicly traded partnerships. Distributable cash flow is presented because we believe it is a useful adjunct to net cash provided by operating activities under GAAP. Distributable cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing or financing activities, as an indicator of cash flows, as a measure of liquidity or as an alternative to net income.

(c) Net income, as adjusted, represents net income adjusted to exclude the effects of impairments, one-time charges related to acquisitions and non-cash changes in the fair value of derivatives. We believe this presentation is commonly used by investors and professional research analysts in the valuation, comparison, rating and investment recommendations of companies in the natural gas midstream industry. We use this information for comparative purposes within the industry. Net income, as adjusted, is not a measure of financial performance under GAAP and should not be considered as a measure of liquidity or as an alternative to net income.

PENN VIRGINIA RESOURCE PARTNERS, L.P.

QUARTERLY SEGMENT INFORMATION - unaudited

(in thousands)

	Eastern Midstream
	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2012			2011		2012			2011
Revenues
Gathering and transportation	$	19,640		$	5,835	$	30,951		$	8,855
Other		1,484			—		1,646			—
Total revenues		21,124			5,835		32,597			8,855
Expenses
Operating		1,189			27		2,087			263
General and administrative		2,276			635		2,890			635
Acquisition related costs		14,049			—		14,049			—
Depreciation, depletion and amortization		8,394			811		10,455			1,164
Total expenses		25,908			1,473		29,481			2,062
Operating income (loss)	$	(4,784	)	$	4,362	$	3,116		$	6,793
	Midcontinent Midstream
	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2012			2011		2012			2011
Revenues
Natural gas	$	63,127		$	112,229	$	137,754		$	204,207
Natural gas liquids		102,130			136,048		219,924			244,890
Gathering and transportation		1,764			2,795		4,308			5,236
Other		928			1,870		1,545			3,688
Total revenues		167,949			252,942		363,531			458,021
Expenses
Cost of gas purchased		140,833			219,278		306,297			389,533
Operating		9,251			10,366		20,478			19,519
General and administrative		5,181			5,906		11,749			11,930
Impairments		—			—		124,845			—
Depreciation, depletion and amortization		11,700			11,753		25,307			23,324
Total expenses		166,965			247,303		488,676			444,306
Operating income (loss)	$	984		$	5,639	$	(125,145	)	$	13,715
	Coal and Natural Resource Management
	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2012			2011		2012			2011
Revenues
Coal royalties	$	29,231		$	44,578	$	62,390		$	83,569
Coal services		1,391			2,278		2,630			4,588
Timber		1,354			1,268		2,873			2,377
Oil and gas royalties		505			989		1,188			1,782
Other		1,358			2,432		4,120			4,657
Total revenues		33,839			51,545		73,201			96,973
Expenses
Operating		3,600			3,849		7,378			7,533
General and administrative		3,542			5,434		8,404			10,380
Depreciation, depletion and amortization		8,362			9,086		16,547			18,406
Total expenses		15,504			18,369		32,329			36,319
Operating income (loss)	$	18,335		$	33,176	$	40,872		$	60,654

PENN VIRGINIA RESOURCE PARTNERS, L.P.

DERIVATIVE CONTRACT SUMMARY - unaudited

As of June 30, 2012

	Average Volume Per			Swap			Weighted Average Price
	Day			Price			Put (a)		Call (b)
NGL - natural gasoline collar		(gallons)						(per gallon)
Third quarter 2012 through fourth quarter 2012		54,000					$	1.75	$	2.02
Crude swap		(barrels	)		(per barrel	)
Third quarter 2012 through fourth quarter 2012		600		$	88.62
Natural gas purchase swap		(MMBtu	)		(MMBtu	)
Third quarter 2012 through fourth quarter 2012		4,000		$	5.195

We estimate that, excluding the effects of derivative positions described above, for every $1.00 per MMBtu increase or decrease in the natural gas price, our natural gas midstream gross margin and operating income (loss) for the remainder of 2012 would increase or decrease by $0.4 million. In addition, we estimate that for every $5.00 per barrel increase or decrease in the crude oil price, our natural gas midstream gross margin and operating income (loss) for the remainder of 2012 would increase or decrease by $4.0 million. This assumes that natural gas prices, crude oil prices and inlet volumes remain constant at anticipated levels. These estimated changes in our gross margin and operating income (loss) exclude potential cash receipts or payments in settling these derivative positions.

(a) - Purchased put/floor.

(b) - Sold call/ceiling.