Edgar Filing: Penn Virginia GP Holdings, L.P.

Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2007

¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 1-33171

PENN VIRGINIA GP HOLDINGS, L.P.

(Exact name of registrant as specified in its charter)

Delaware

20-5116532

(State or other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

THREE RADNOR CORPORATE CENTER, SUITE 300

100 MATSONFORD ROAD

RADNOR, PA 19087

(Address of principal executive offices) (Zip Code)

(610) 687-8900

(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. x Yes ¨ No

Indicate by a check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ¨ Accelerated filer ¨ Non-accelerated filer x

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ¨ Yes x No

As of August 1, 2007, 39,074,500 common limited partner units were outstanding.

PENN VIRGINIA GP HOLDINGS, L.P. AND SUBSIDIARIES

INDEX


		Page
PART I.	Financial Information

Item 1.	Financial Statements

	Condensed Consolidated Statements of Income for the Three Months and Six Months Ended June 30, 2007 and 2006	1

	Condensed Consolidated Balance Sheets as of June 30, 2007 and December 31, 2006	2

	Condensed Consolidated Statements of Cash Flows for the Three Months and Six Months Ended June 30, 2007 and 2006	3

	Notes to Condensed Consolidated Financial Statements	4

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	12

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	30

Item 4.	Controls and Procedures	31

PART II.	Other Information

Item 6.	Exhibits	33

PART I. FINANCIAL INFORMATION

Item 1

Financial Statements

PENN VIRGINIA GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME – unaudited

(in thousands, except per unit data)


	Three Months Ended June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
Revenues
Natural gas midstream	$	114,407		$	95,350		$	209,725		$	204,531
Coal royalties		24,029			24,254			49,029			46,676
Coal services		2,092			1,404			3,693			2,830
Other		3,616			2,455			5,897			4,590

Total revenues		144,144			123,463			268,344			258,627

Expenses
Cost of midstream gas purchased		95,077			75,692			174,808			174,343
Operating		5,497			4,094			11,011			7,572
Taxes other than income		607			438			1,450			1,136
General and administrative		6,305			5,134			12,706			10,404
Depreciation, depletion and amortization		9,822			8,816			19,955			17,637

Total expenses		117,308			94,174			219,930			211,092

Operating income		26,836			29,289			48,414			47,535

Other income (expense)
Interest expense		(3,617	)		(4,416	)		(7,164	)		(8,483	)
Other		466			277			819			571
Derivatives		(7,550	)		(11,929	)		(10,197	)		(18,062	)

Income from operations before minority interest		16,135			13,221			31,872			21,561
Minority interest		(7,834	)		(7,759	)		(15,851	)		(12,648	)

Net income	$	8,301		$	5,462		$	16,021		$	8,913

Basic and diluted net income per limited partner unit	$	0.21		$	0.17		$	0.41		$	0.28

Weighted average number of units outstanding, basic and diluted		39,075			32,125			39,067			32,125

The accompanying notes are an integral part of these condensed consolidated financial statements.

PENN VIRGINIA GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)


	June 30, 2007			December 31, 2006
	(unaudited)
Assets
Current assets
Cash and cash equivalents	$	22,212		$	13,687
Accounts receivable		70,589			66,987
Derivative assets		1,740			449
Other current assets		2,421			2,587

Total current assets		96,962			83,710

Property, plant and equipment		732,967			665,135
Accumulated depreciation, depletion and amortization		(126,370	)		(108,622	)

Net property, plant and equipment		606,597			556,513

Derivative assets		2,169			2,455
Other long-term assets		72,179			73,591

Total assets	$	777,907		$	716,269

Liabilities and Partners’ Capital
Current liabilities
Accounts payable and accrued liabilities	$	63,786		$	63,340
Current portion of long-term debt		11,846			10,832
Deferred income		6,662			6,999
Derivative liabilities		14,888			6,996

Total current liabilities		97,182			88,167

Deferred income		3,457			6,592
Other liabilities		3,493			3,339
Derivative liabilities		5,438			6,618
Long-term debt of PVR		263,283			207,214

Minority interests in PVR		172,850			330,148

Partners’ capital		232,204			74,191

Total liabilities and partners’ capital	$	777,907		$	716,269

The accompanying notes are an integral part of these condensed consolidated financial statements.

PENN VIRGINIA GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited

(in thousands)


	Three Months Ended June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
Cash flows from operating activities
Net income	$	8,301		$	5,461		$	16,021		$	8,912
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization		9,822			8,816			19,955			17,637
Commodity derivative contracts:
Total derivative losses		8,835			12,640			12,325			18,512
Cash settlements on derivatives		(2,189	)		(5,139	)		(4,261	)		(8,061	)
Non-cash interest expense		165			191			329			382
Minority interest		7,834			7,759			15,851			12,648
Equity earnings, net of distributions received		(645	)		2,358			(878	)		2,028
Other		(158	)		420			(198	)		729
Changes in operating assets and liabilities		1,580			3,667			(2,972	)		(4,341	)

Net cash provided by operating activities		33,545			36,173			56,172			48,446

Cash flows from investing activities
Acquisitions		(52,117	)		(78,318	)		(52,456	)		(81,387	)
Additions to property, plant and equipment		(11,872	)		(9,825	)		(18,874	)		(15,321	)
Other		154			3			197			3

Net cash used in investing activities		(63,835	)		(88,140	)		(71,133	)		(96,705	)

Cash flows from financing activities
Distributions to partners		(21,032	)		(14,475	)		(34,374	)		(28,923	)
Proceeds from borrowings		52,000			64,800			62,000			64,800
Repayments of borrowings		—			—			(5,000	)		(3,300	)
Proceeds from issuance of common units		—			—			916			—
Payment of offering costs		—			—			(56	)		—

Net cash provided by financing activities		30,968			50,325			23,486			32,577

Net increase (decrease) in cash and cash equivalents		678			(1,642	)		8,525			(15,682	)
Cash and cash equivalents – beginning of period		21,534			9,110			13,687			23,150

Cash and cash equivalents – end of period	$	22,212		$	7,468		$	22,212		$	7,468

Supplemental disclosure:
Cash paid for interest	$	2,369		$	3,511		$	6,903		$	8,863

The accompanying notes are an integral part of these condensed consolidated financial statements.

PENN VIRGINIA GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – unaudited

June 30, 2007

1. Organization

Penn Virginia GP Holdings, L.P. (the “Partnership,” “we,” “us” or “our”) is a Delaware limited partnership formed in June 2006 that currently owns 100% of the general partner of Penn Virginia Resource Partners, L.P. (“PVR”), which holds a 2% general partner interest in PVR and an approximately 42% limited partner interest in PVR. Our only cash generating assets consist of our partnership interests in PVR. Due to our control of the general partner of PVR, the financial results of PVR are included in our condensed consolidated financial statements. However, PVR functions with a capital structure that is independent of ours, consisting of its own debt instruments and publicly traded common units.

Our general partner is an indirect wholly-owned subsidiary of Penn Virginia Corporation (“Penn Virginia”). Penn Virginia and its subsidiaries own an approximately 82% limited partner interest in us. We own 100% of Penn Virginia Resource GP, LLC, a Delaware limited liability company and the general partner of PVR. PVR is a Delaware limited partnership formed by Penn Virginia in July 2001 primarily to engage in the business of managing coal properties in the United States. PVR completed its initial public offering (the “PVR IPO”) in October 2001. Effective with the closing of the PVR IPO, Penn Virginia, through its wholly-owned subsidiaries, received common and subordinated units of PVR and a 2% general partner interest in PVR.

We completed our initial public offering in December 2006, selling approximately 18% of our outstanding common units to the public and using the proceeds from the offering to purchase 416,444 newly issued common units and 4,045,311 newly issued Class B units from PVR. As of June 30, 2007, we owned approximately 44% of PVR, consisting of a 2% general partner interest and an approximately 42% limited partner interest. As part of our ownership of PVR’s general partner, we also own the rights, referred to as “incentive distribution rights,” to receive an increasing percentage of PVR’s quarterly distributions of available cash from operating surplus after certain levels of cash distributions have been achieved.

2. Summary of Significant Accounting Policies

Our accounting policies are consistent with those described in our Annual Report on Form 10-K for the year ended December 31, 2006. Please refer to such Form 10-K for a further discussion of those policies.

Basis of Presentation

Unless otherwise indicated, for the purposes of these financial statements, the “Partnership,” “we,” “us” or “our” refers to Penn Virginia GP Holdings, L.P. and subsidiaries. References to the “parent company” are intended to mean Penn Virginia GP Holdings, L.P. individually as the parent company and not on a consolidated basis.

In accordance with generally accepted accounting principles, the distribution of net assets from the parent company to affiliates of Penn Virginia in December 2006 was accounted for as a reorganization of entities under common control in a manner similar to a pooling of interests. As a result, our historical condensed consolidated financial information presented in this Quarterly Report on Form 10-Q for periods prior to our receipt of contributions from Penn Virginia has been presented using the condensed consolidated financial information of Penn Virginia Resource GP, LLC and subsidiaries, which was our predecessor company.

The presentation of such predecessor condensed consolidated financial information assumes that the historical ownership interests in PVR held by affiliates of Penn Virginia (prior to the contribution of net assets in December 2006) were owned by the parent company. This method of presentation is substantially on the same basis that our condensed consolidated results of operations and financial position have been presented since the contribution of net assets from affiliates of Penn Virginia.

The condensed consolidated financial statements include the accounts of the Partnership, all of its wholly-owned subsidiaries and PVR, of which we indirectly owned the sole 2% general partner interest and an approximately 42% limited partner interest as of June 30, 2007. Penn Virginia Resource GP, LLC, our wholly-

owned subsidiary, serves as PVR’s general partner and controls PVR. Intercompany balances and transactions have been eliminated in consolidation. The financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial reporting and Securities and Exchange Commission regulations. 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 the condensed consolidated financial statements have been included. These financial statements should be read in conjunction with our condensed consolidated financial statements and footnotes included in our Annual Report on Form 10-K for the year ended December 31, 2006. Operating results for the three months and six months ended June 30, 2007 are not necessarily indicative of the results that may be expected for the year ending December 31, 2007.

New Accounting Standards

In September 2006, the Financial Accounting Standards Board (the “FASB”) issued Statement of Financial Accounting Standards (“SFAS”) No. 157, Fair Value Measurements, a standard that provides enhanced guidance for using fair value to measure assets and liabilities. SFAS No. 157 also responds to investors’ requests for expanded information about the extent to which companies measure assets and liabilities at fair value, the information used to measure fair value and the effect of fair value measurements on earnings. SFAS No. 157 applies whenever other standards require (or permit) assets or liabilities to be measured at fair value. SFAS No. 157 does not expand the use of fair value in any new circumstances. SFAS No. 157 establishes a fair value hierarchy that prioritizes the information used to develop fair value assumptions. SFAS No. 157 is effective for fiscal years and interim periods beginning after November 15, 2007. We have not yet determined the impact on our condensed consolidated financial statements of adopting SFAS No. 157 effective January 1, 2008.

In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115, which provides companies with an option to report selected financial assets and liabilities at fair value. The objective of SFAS No. 159 is to reduce both complexity in accounting for financial instruments and the volatility in earnings caused by measuring related assets and liabilities differently. SFAS No. 159 also establishes presentation and disclosure requirements designed to facilitate comparisons between companies that choose different measurement attributes for similar types of assets and liabilities. SFAS No. 159 is effective as of the beginning of an entity’s first fiscal year beginning after November 15, 2007. We have not yet determined the impact on our condensed consolidated financial statements of adopting SFAS No. 159 effective January 1, 2008.

3. Acquisitions

PVR Coal Segment

On June 11, 2007, PVR acquired from a private seller approximately 9 million tons of coal reserves. This property is located on approximately 1,700 acres in Jackson County, Illinois. The purchase price was $9.9 million in cash and was funded with long-term debt under PVR’s revolving credit facility.

On June 29, 2007, PVR acquired from a private seller the fee ownership or lease rights to approximately 51 million tons of coal reserves, along with a preparation plant and coal handling facilities. This property is located on approximately 17,000 acres in Webster and Hopkins Counties, Kentucky. The purchase price was $42.0 million in cash and was funded with long-term debt under PVR’s revolving credit facility. The assets have been recorded as a component of property, plant and equipment; however, the purchase price allocation for this acquisition has not been finalized.

4. Gain on Sale of Subsidiary Units

We accounted for the PVR IPO and each subsequent PVR equity issuance as a sale of a minority interest. For each PVR equity issuance, we calculated a gain under SEC Staff Accounting Bulletin No. 51 (or Topic 5-H), Accounting for Sales of Stock by a Subsidiary (“SAB 51”). Because the PVR common units had preference over the PVR subordinated units with respect to distributions, the gain was not recognized at the time of each PVR equity issuance. This gain was to be recognized in partners’ capital when all of the subordinated units converted to

common units. By November 2006, all of the subordinated units had converted to common units. However, because the issuance of the PVR Class B units, which were subordinate to the PVR common units with respect to distributions, was contemplated at the time the final PVR subordinated units converted to PVR common units in November 2006, we did not recognize the SAB 51 gain at the time. After the conversion of the Class B units to common units on a one-for-one basis in May 2007, PVR no longer had any form of junior securities outstanding. Accordingly, we recognized a $151.7 million gain in partners’ capital related to PVR equity issuances from the time of the PVR IPO in October 2001 to May 2007. SAB 51 gains will be recognized with respect to future PVR equity issuances at the time of the equity issuances as long PVR does not have any junior securities outstanding and is not contemplating the issuance of junior securities.

5. Derivative Instruments

PVR Natural Gas Midstream Segment Commodity Derivatives

PVR utilizes swap derivative contracts to hedge against the variability in cash flows associated with forecasted natural gas midstream revenues and cost of midstream gas purchased. While the use of derivative instruments limits the risk of adverse price movements, their use also may limit future revenues or cost savings from favorable price movements.

With respect to a swap contract, the counterparty is required to make a payment to PVR if the settlement price for any settlement period is less than the swap price for such contract, and we are required to make a payment to the counterparty if the settlement price for any settlement period is greater than the swap price for such contract.

The fair values of PVR’s derivative agreements are determined based on forward price quotes for the respective commodities as of June 30, 2007. The following table sets forth PVR’s positions as of June 30, 2007 for commodities related to natural gas midstream revenues (ethane, propane, natural gas and crude oil) and cost of midstream gas purchased (natural gas and crude oil):


	Average Volume Per Day	Weighted Average Price		Weighted Average Collars				Estimated Fair Value
	Average Volume Per Day	Weighted Average Price		Put		Call		Estimated Fair Value
Ethane Swaps	(in gallons)	(per gallon)						(in thousands)
Third Quarter 2007 through Fourth Quarter 2007	34,440	$	0.5050					$	(1,421	)
First Quarter 2008 through Fourth Quarter 2008	34,440	$	0.4700						(2,344	)

Propane Swaps	(in gallons)	(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	26,040	$	0.7550						(1,952	)
First Quarter 2008 through Fourth Quarter 2008	26,040	$	0.7175						(3,820	)

Crude Oil Swaps	(in barrels)	(per barrel)
Third Quarter 2007 through Fourth Quarter 2007	560	$	50.80						(2,071	)
First Quarter 2008 through Fourth Quarter 2008	560	$	49.27						(4,473	)

Natural Gas Swaps	(in MMbtu)	(per MMbtu)
Third Quarter 2007 through Fourth Quarter 2008	4,000	$	6.97						2,258

Natural Gasoline Swap/Crude Oil Swap	(in gallons /in barrels)	(per gallon /per barrel)
Third Quarter 2007 through Fourth Quarter 2007	23,520 /560	$	1.265 /57.12						(294	)

Ethane Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	5,000			$	0.6100	$	0.7125		(52	)

Propane Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	9,000			$	1.0300	$	1.1640		(72	)

Natural Gasoline Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2008	6,300			$	1.4800	$	1.6465		(380	)

Crude Oil Collar	(in barrels)			(per barrel)
First Quarter 2008 through Fourth Quarter 2008	400			$	65.00	$	75.25		(226	)

Frac Spread	(in MMbtu)	(per MMbtu)
Third Quarter 2007 through Fourth Quarter 2007	7,128	$	4.299						(2,196	)

Settlements to be paid in subsequent period									(1,026	)

Natural gas midstream segment commodity derivatives - net liability								$	(18,069	)

At June 30, 2007, PVR reported (i) a net derivative liability related to the natural gas midstream segment of $18.1 million and (ii) a loss in accumulated other comprehensive income of $7.9 million related to derivatives in the natural gas midstream segment for which PVR discontinued cash flow hedge accounting in 2006. The following table summarizes the effects of commodity derivative activities on PVR’s condensed consolidated statements of income:


	Three Months Ended June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
	(in thousands)						(in thousands)
Income statement caption:
Midstream revenue	$	(2,050	)	$	(2,564	)	$	(4,336	)	$	(4,732	)
Cost of gas purchased		765			1,853			2,208			4,282
Derivatives		(7,550	)		(11,929	)		(10,197	)		(18,062	)

Increase (decrease) in net income	$	(8,835	)	$	(12,640	)	$	(12,325	)	$	(18,512	)

Realized and unrealized derivative impact:
Cash paid for derivative settlements	$	(2,189	)	$	(5,139	)	$	(4,261	)	$	(8,061	)
Unrealized derivative gain (loss)		(6,646	)		(7,501	)		(8,064	)		(10,451	)

Increase (decrease) in net income	$	(8,835	)	$	(12,640	)	$	(12,325	)	$	(18,512	)

Interest Rate Swaps

In September 2005, PVR entered into interest rate swap agreements (the “PVR Revolver Swaps”) to establish fixed rates on $60 million of the portion of the outstanding balance on its revolving credit facility that is based on the London Inter Bank Offering Rate (“LIBOR”) until March 2010. PVR pays a weighted average fixed rate of 4.22% on the notional amount plus the applicable margin, and the counterparties pay a variable rate equal to the three-month LIBOR. Settlements on the PVR Revolver Swaps are recorded as interest expense. The PVR Revolver Swaps were designated as cash flow hedges. Accordingly, the effective portion of the change in the fair value of the swap transactions is recorded each period in other comprehensive income. The ineffective portion of the change in fair value, if any, is recorded to current period earnings as interest expense. PVR reported (i) a derivative asset of approximately $1.7 million at June 30, 2007 and (ii) a gain in accumulated other comprehensive income of $1.7 million at June 30, 2007 related to the PVR Revolver Swaps. In connection with periodic settlements, PVR recognized $0.3 million in net hedging gains in interest expense for the six months ended June 30, 2007.

6. Cash Distributions

We paid a pro rata quarterly distribution of $0.07 per unit, or $0.96 per unit on an annualized basis, in February 2007, and we paid a quarterly distribution of $0.26 per unit, or $1.04 per unit on an annualized basis, in May 2007. In July 2007, we announced a $0.28 per unit distribution for the three months ended June 30, 2007, or $1.12 per unit on an annualized basis. The distribution will be paid on August 20, 2007 to unitholders of record at the close of business on August 6, 2007.

7. Related Party Transactions

General and Administrative

Penn Virginia charges us for certain corporate administrative expenses which are allocable to us and our subsidiaries. When allocating general corporate expenses, consideration is given to property and equipment, payroll and general corporate overhead. Any direct costs are paid by us. Total corporate administrative expenses charged to us totaled $6.3 million and $5.1 million for the three months ended June 30, 2007 and 2006 and $12.7 and $10.4 million for the six months ended June 30, 2007 and 2006. These costs are reflected in general and administrative expenses in our condensed consolidated statements of income. At least annually, management performs an analysis of general corporate expenses based on time allocations of shared employees and other pertinent factors. Based on this analysis, management believes the allocation methodologies used are reasonable.

Accounts Payable—Affiliate

Amounts payable to related parties totaled $2.4 million as of June 30, 2007. This balance consists primarily of amounts due to Penn Virginia for general and administrative expenses incurred on our behalf and is included in accounts payable on our condensed consolidated balance sheets.

Marketing Revenues

Connect Energy Services, LLC, a wholly-owned subsidiary of PVR, earned $0.6 million and $1.0 million in fees for marketing a portion of Penn Virginia Oil & Gas, L.P.’s natural gas production during the three months and six months ended June 30, 2007. The marketing agreement was effective September 1, 2006. Penn Virginia Oil & Gas, L.P. is a wholly-owned subsidiary of Penn Virginia. Marketing revenues are included in other revenues on our condensed consolidated statements of income.

8. PVR Long-Term Incentive Plan

PVR recognized compensation expense related to the granting of common units and deferred common units and the vesting of restricted units granted under the long-term incentive plan of PVR’s general partner to employees of Penn Virginia who perform services for PVR. For the three months ended June 30, 2007 and 2006, PVR recognized a total of $0.6 million and $0.9 million of compensation expense related to the long-term incentive plan. For the six months ended June 30, 2007 and 2006, PVR recognized a total of $1.1 million and $1.3 million of compensation expense related to the long-term incentive plan.

During the six months ended June 30, 2007, 85,233 PVR restricted units with a weighted average grant date fair value of $26.85 per unit were granted to employees of Penn Virginia who perform services for PVR. During the same period, 42,582 PVR restricted units with a weighted average grant date fair value of $27.56 per unit vested. PVR restricted units granted in 2007 vest over a three-year period, with one third vesting in each year. We recognize compensation expense on a straight-line basis over the vesting period.

9. Comprehensive Income

Comprehensive income represents certain changes in partners’ capital during the reporting period, including net income and charges directly to partners’ capital which are excluded from net income. For the three months and six months ended June 30, 2007 and 2006, the components of comprehensive income were as follows:


	Three Months Ended June 30,					Six Months Ended June 30,
	2007		2006			2007		2006
	(in thousands)					(in thousands)
Net income	$	8,301	$	5,461		$	16,021	$	8,912
Unrealized holding losses on derivative activities		771		(2,819	)		571		(4,785	)
Reclassification adjustment for derivative activities		1,112		604			1,784		764

Comprehensive income	$	10,184	$	3,246		$	18,376	$	4,891

10. 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, management believes these claims will not have a material effect on our financial position, liquidity or operations.

Environmental Compliance

The operations of PVR’s coal lessees and PVR’s natural gas midstream segment are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdictions in which these operations are conducted. The terms of PVR’s coal property leases impose liability for all environmental and reclamation liabilities arising under those laws and regulations on the relevant lessees. The lessees are bonded and have indemnified PVR against any and all future environmental liabilities. PVR regularly visits coal properties under lease to monitor lessee compliance with environmental laws and regulations and to review mining activities. PVR’s management believes that the operations of PVR’s coal lessees and PVR’s natural gas midstream segment comply with existing regulations and does not expect any material impact on its financial condition or results of operations.

As of June 30, 2007, PVR’s environmental liabilities included $1.5 million, which represents PVR’s best estimate of its liabilities as of that date related to its coal and natural gas midstream businesses. PVR has 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.

Mine Health and Safety Laws

There are numerous mine health and safety laws and regulations applicable to the coal mining industry. However, since PVR does not operate any coal mines and does not employ any coal miners, PVR is not subject to such laws and regulations. Accordingly, we have not accrued any related liabilities.

11. Segment Information

Segment information has been prepared in accordance with SFAS No. 131, Disclosure about Segments of an Enterprise and Related Information. Under SFAS No. 131, operating segments are defined as components of an enterprise about which separate financial information is available and is evaluated regularly by the chief operating decision maker, or decision-making group, in assessing performance. Our chief operating decision-making group consists of our Chief Executive Officer and other senior officers. This group routinely reviews and makes operating and resource allocation decisions among our coal operations and our natural gas midstream operations. Accordingly, our reportable segments are as follows:

•

PVR Coal – management and leasing of coal properties and subsequent collection of royalties; other land management activities such as selling standing timber and real estate rentals; leasing of fee-based coal-related infrastructure facilities to certain lessees and end-user industrial plants.

•

PVR Natural Gas Midstream – natural gas processing, natural gas gathering and other related services.

The following table presents a summary of certain financial information relating to our segments:


	Coal		Natural Gas Midstream		Other			Consolidated
	(in thousands)
For the Three Months Ended June 30, 2007:
Revenues	$	28,410	$	115,734	$	—		$	144,144
Cost of midstream gas purchased		—		95,077		—			95,077
Operating costs and expenses		5,524		6,339		546			12,409
Depreciation, depletion and amortization		5,320		4,502		—			9,822

Operating income	$	17,566	$	9,816	$	(546	)		26,836

Interest expense									(3,617	)
Other									466
Derivatives									(7,550	)
Minority interest									(7,834	)

Net income								$	8,301

Additions to property and equipment	$	52,130	$	11,859	$	—		$	63,989

For the Three Months Ended June 30, 2006:
Revenues	$	27,898	$	95,565	$	—		$	123,463
Cost of midstream gas purchased		—		75,692		—			75,692
Operating costs and expenses		3,822		5,844		—			9,666
Depreciation, depletion and amortization		4,747		4,069		—			8,816

Operating income	$	19,329	$	9,960	$	—			29,289

Interest expense									(4,416	)
Other									277
Derivatives									(11,929	)
Minority interest									(7,759	)

Net income								$	5,462

Additions to property and equipment	$	69,163	$	18,980	$	—		$	88,143


	Coal		Natural Gas Midstream		Other			Consolidated
	(in thousands)
For the Six Months Ended June 30, 2007:
Revenues	$	56,894	$	211,450	$	—		$	268,344
Cost of midstream gas purchased		—		174,808		—			174,808
Operating costs and expenses		10,618		13,241		1,308			25,167
Depreciation, depletion and amortization		10,810		9,145		—			19,955

Operating income	$	35,466	$	14,256	$	(1,308	)		48,414

Interest expense									(7,164	)
Other									819
Derivatives									(10,197	)
Minority interest									(15,851	)

Net income								$	16,021

Additions to property and equipment	$	53,466	$	17,864	$	—		$	71,330

For the Six Months Ended June 30, 2006:
Revenues	$	53,226	$	205,401	$	—		$	258,627
Cost of midstream gas purchased		—		174,343		—			174,343
Operating costs and expenses		7,331		11,781		—			19,112
Depreciation, depletion and amortization		9,499		8,138		—			17,637

Operating income	$	36,396	$	11,139	$	—			47,535

Interest expense									(8,483	)
Other									571
Derivatives									(18,062	)
Minority interest									(12,648	)

Net income								$	8,913

Additions to property and equipment	$	75,167	$	21,541	$	—		$	96,708

Item 2

Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of the financial condition and results of operations of Penn Virginia GP Holdings, L.P. (the “Partnership,” “we,” “us” or “our”) should be read in conjunction with our condensed consolidated financial statements and the accompanying notes in Item 1, “Financial Statements.” Our discussion and analysis include the following items:

•

Overview of Our Business

•

Overview of PVR’s Business

•

Acquisitions and Investments

•

Liquidity and Capital Resources

•

Results of Operations

•

Summary of Critical Accounting Policies and Estimates

•

Environmental Matters

•

Recent Accounting Pronouncements

•

Forward-Looking Statements

Overview of Our Business

General

We are a publicly traded Delaware limited partnership formed by Penn Virginia Corporation (“Penn Virginia”) in June 2006. Our only cash generating assets consist of our partnership interests in PVR which consist of the following:

•

a 2% general partner interest in Penn Virginia Resource Partners, L.P., (“PVR”), which we hold through our 100% ownership interest in Penn Virginia Resource GP, LLC, PVR’s general partner;

•

all of the incentive distribution rights in PVR, which we hold through our 100% ownership interest in PVR’s general partner; and

•

an approximately 42% limited partner interest in PVR.

All of our cash flows are generated from the cash distributions we receive with respect to the PVR partnership interests we own. PVR is required by its partnership agreement to distribute, and it has historically distributed within 45 days of the end of each quarter, all of its cash on hand at the end of each quarter, less cash reserves established by its general partner in its sole discretion to provide for the proper conduct of PVR’s business or to provide for future distributions. While we, like PVR, are structured as a limited partnership, our capital structure and cash distribution policy differ materially from those of PVR. Most notably, our general partner does not have an economic interest in us and is not entitled to receive any distributions from us and our capital structure does not include incentive distribution rights. Therefore, our distributions are allocated exclusively to our common units, which is our only class of security currently outstanding.

Our ownership of PVR’s incentive distribution rights entitles us to receive the following percentages of cash distributed by PVR as it reaches the following target cash distribution levels:

•

13% of all incremental cash distributed in a quarter after $0.275 has been distributed in respect of each common unit of PVR for that quarter;

•

23% of all incremental cash distributed after $0.325 has been distributed in respect of each common unit of PVR for that quarter; and

•

the maximum sharing level of 48% of all incremental cash distributed after $0.375 has been distributed in respect of each common unit of PVR for that quarter.

Since 2001, PVR has increased its quarterly cash distribution from $0.25 per unit ($1.00 on an annualized basis) to $0.42 per unit ($1.68 on an annualized basis), which is the most recently declared distribution. These increased cash distributions by PVR have placed us at the third and maximum target cash distribution level as described

above. As a consequence, any increase in cash distribution level from PVR will allow us to share at the 48% level and the cash distributions we receive from PVR with respect to our indirect ownership of the incentive distribution rights will increase more rapidly than those with respect to our ownership of the general partner interest and limited partner interests. Because we are at the maximum target cash distribution level on the incentive distribution rights, future growth in distributions we receive from PVR will not result from an increase in the target cash distribution level associated with the incentive distribution rights.

Financial Presentation

We reflect our ownership interest in PVR on a consolidated basis, which means that our financial results are combined with PVR’s financial results and the results of our other subsidiaries. The 48% limited partner interest in PVR that we do not own, after the effect of incentive distribution rights, is reflected as a minority interest in our condensed consolidated statements of income. We have no separate operating activities apart from those conducted by PVR, and our cash flows currently consist of distributions from PVR on the partnership interests, including the incentive distribution rights that we own. Accordingly, the discussion and analysis of our financial position and results of operations in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” reflects the operating activities and results of operations of PVR. The historical results of our operations do not reflect the incremental expenses we expect to incur as a result of being a publicly traded limited partnership.

Overview of PVR’s Business

PVR is a publicly traded Delaware limited partnership formed by Penn Virginia in 2001 that is principally engaged in the management of coal properties and the gathering and processing of natural gas in the United States. Both in its current limited partnership form and in its previous corporate form, PVR has managed coal properties since 1882. We consolidate PVR’s results into our financial statements. For the six months ended June 30, 2007, we had an approximately 52% interest in PVR’s net income, including incentive distribution rights. PVR currently conducts operations in two business segments: coal and natural gas midstream. Operating income for the six months ended June 30, 2007 was $48.4 million, compared to $47.5 million for the six months ended June 30, 2006. For the six months ended June 30, 2007, the PVR coal segment contributed $35.5 million, or 73%, to operating income, and the PVR natural gas midstream segment contributed $14.3 million, or 29%. Corporate and other functions resulted in approximately $1.3 million of operating expenses. The following table presents a summary of certain financial information relating to our segments:


	Coal		Natural Gas Midstream		Other			Consolidated
	(in thousands)
For the Six Months Ended June 30, 2007:
Revenues	$	56,894	$	211,450	$	—		$	268,344
Cost of midstream gas purchased		—		174,808		—			174,808
Operating costs and expenses		10,618		13,241		1,308			25,167
Depreciation, depletion and amortization		10,810		9,145		—			19,955

Operating income	$	35,466	$	14,256	$	(1,308	)	$	48,414

For the Six Months Ended June 30, 2006:
Revenues	$	53,226	$	205,401	$	—		$	258,627
Cost of midstream gas purchased		—		174,343		—			174,343
Operating costs and expenses		7,331		11,781		—			19,113
Depreciation, depletion and amortization		9,499		8,138		—			17,637

Operating income	$	36,396	$	11,139	$	—		$	47,534

PVR Coal Segment

As of December 31, 2006, PVR owned or controlled approximately 765 million tons of proven and probable coal reserves in Central and Northern Appalachia, the San Juan Basin and the Illinois Basin. PVR enters into long-

term leases with experienced, third-party mine operators providing them the right to mine its coal reserves in exchange for royalty payments. PVR does not operate any coal mines. In the six months ended June 30, 2007, PVR’s lessees produced 16.3 million tons of coal from its properties and paid PVR coal royalty revenues of $49.0 million, for an average gross coal royalty per ton of $3.00. Approximately 81% of PVR’s coal royalty revenues in the six months ended June 30, 2007 and 2006 were derived from coal mined on PVR properties under leases containing royalty rates based on the higher of a fixed base price or a percentage of the gross sales price. The balance of its coal royalty revenues for the respective periods was derived from coal mined on PVR properties under leases containing fixed royalty rates that escalate annually.

Coal royalties are impacted by several factors that PVR generally cannot control. The number of tons mined annually 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. The possibility exists that new legislation or regulations have or may be adopted which may have a significant impact on the mining operations of PVR’s lessees or their customers’ ability to use coal and which may require PVR, its lessees or its lessee’s customers to change operations significantly or incur substantial costs.

Coal prices also impact coal royalty revenues. Coal prices, especially in Central Appalachia where the majority of PVR’s coal is produced, increased significantly from the beginning of 2004 through most of 2006. The price increase during that period was primarily the result of increased electricity demand, rebuilding of inventories and decreasing coal production in Central Appalachia. In the second half of 2006 and continuing into 2007, coal prices decreased from the historically high levels experienced in the previous two and one half years, due to higher than normal coal inventories at electric utilities and milder than normal winter weather.

Substantially all of PVR’s leases require the lessee to pay minimum rental payments to PVR in monthly or annual installments. PVR actively works with its lessees to develop efficient methods to exploit its reserves and to maximize production from its properties. PVR also earns revenues from providing fee-based coal preparation and transportation services to its lessees, which enhance their production levels and generate additional coal royalty revenues, and from industrial third party coal end-users by owning and operating coal handling facilities through its joint venture with Massey Energy Company. In addition, PVR earns revenues from oil and gas royalty interests it owns, from coal transportation rights and from the sale of standing timber on its properties.

PVR Natural Gas Midstream Segment

PVR owns and operates natural gas midstream assets located in Oklahoma and the panhandle of Texas. These assets include approximately 3,655 miles of natural gas gathering pipelines and three natural gas processing facilities having 160 million cubic feet per day (“MMcfd”) of total capacity. PVR’s natural gas midstream business derives revenues primarily from gas processing contracts with natural gas producers and from fees charged for gathering natural gas volumes and providing other related services. PVR also owns a natural gas marketing business, which aggregates third-party volumes and sells those volumes into intrastate pipeline systems and at market hubs accessed by various interstate pipelines.

For the six months ended June 30, 2007, system throughput volumes at PVR’s gas processing plants and gathering systems, including gathering-only volumes, were 32.9 billion cubic feet, or 182 MMcfd, and three of PVR’s natural gas midstream customers accounted for 53% of PVR’s natural gas midstream revenues.

PVR continually seeks new supplies of natural gas to both offset the natural declines in production from the wells currently connected to its systems and to increase system throughput volumes. New natural gas supplies are obtained for all of PVR’s systems by contracting for production from new wells, connecting new wells drilled on dedicated acreage and by contracting for natural gas that has been released from competitors’ systems.

Revenues, profitability and the future rate of growth of the natural gas midstream segment are highly dependent on market demand and prevailing natural gas liquid (“NGL”) and natural gas prices. Historically, changes in the prices of most NGL products have generally correlated with changes in the price of crude oil. NGL and natural gas prices have been subject to significant volatility in recent years in response to changes in the supply and demand for NGL products and natural gas market uncertainty.

Acquisitions and Investments

Liquidity and Capital Resources

We rely exclusively on distributions from PVR to fund any cash requirements for our operations. PVR generally satisfies its working capital requirements and funds its capital expenditures and debt service obligations from cash generated from its operations and borrowings under its revolving credit facility. PVR believes that the cash generated from PVR’s operations and its borrowing capacity will be sufficient to meet its working capital requirements, anticipated capital expenditures (other than major capital improvements or acquisitions), scheduled debt payments and distribution payments. PVR’s ability to satisfy its obligations and planned expenditures will depend upon PVR’s future operating performance, which will be affected by, among other things, prevailing economic conditions in the coal industry and the natural gas midstream market, some of which are beyond PVR’s control.

Cash Flows

Except where noted, the following discussion of cash flows and capital expenditures relates to our consolidated results.

The following table summarizes our cash flow statements for the six months ended June 30, 2007 and 2006, consolidating our segments (in thousands):


For the Six Months Ended June 30, 2007	Coal			Natural Gas Midstream			Other			Consolidated
Cash flows from operating activities:
Net income contribution	$	28,521		$	4,472		$	(16,972	)	$	16,021
Adjustments to reconcile net income to net cash provided by operating activities (summarized)		10,064			17,209			15,850			43,123
Net change in operating assets and liabilities		(5,523	)		2,573			(22	)		(2,972	)

Net cash provided by (used in) operating activities	$	33,062		$	24,254		$	(1,144	)		56,172

Net cash used in investing activities	$	(53,269	)	$	(17,864	)	$	—			(71,133	)

Net cash provided by financing activities											23,486

Net increase in cash and cash equivalents										$	8,525


For the Six Months Ended June 30, 2006	Coal			Natural Gas Midstream			Other			Consolidated
Cash flows from operating activities:
Net income contribution	$	28,068		$	(6,507	)	$	(12,649	)	$	8,912
Adjustments to reconcile net income to net cash provided by operating activities (summarized)		11,906			18,592			13,377			43,875
Net change in operating assets and liabilities		(2,040	)		500			(2,810	)		(4,350	)

Net cash provided by (used in) operating activities	$	37,934		$	12,585		$	(2,082	)		48,437

Net cash used in investing activities	$	(75,162	)	$	(21,543	)	$	—			(96,705	)

Net cash provided by financing activities											32,577

Net decrease in cash and cash equivalents										$	(15,691	)

Cash provided by operating activities increased $7.8 million, or 16%, to $56.2 million for the six months ended June 30, 2007 from $48.4 million for the same period in 2006. The overall increase in cash provided by operating activities for the six months ended June 30, 2007 compared to the same period in 2006 was primarily attributable to an increase in coal royalty revenues, an increase in natural gas midstream production and an overall increase in working capital.

During the six months ended June 30, 2007, PVR made aggregate capital expenditures of $69.8 million primarily for coal reserve acquisitions and natural gas midstream gathering system expansion projects. During the six months ended June 30, 2006, PVR made aggregate capital expenditures of $96.4 million primarily for coal reserve acquisitions and the acquisition of pipeline and compression facilities. Capital expenditures comprise the primary portion of cash used in investing activities. The following table sets forth capital expenditures by segment made during the periods indicated:


	Six Months Ended June 30,
	2007		2006
	(in thousands)
Coal
Acquisitions	$	52,456	$	66,382
Expansion capital expenditures		52		43
Other property and equipment expenditures		85		7,691

Total		52,593		74,116

Natural gas midstream
Acquisitions, net of cash acquired		—		14,626
Expansion capital expenditures		12,540		3,392
Other property and equipment expenditures		4,635		4,278

Total		17,175		22,296

Total capital expenditures	$	69,768	$	96,412

Capital expenditures in the six months ended June 30, 2007 and 2006 were funded with cash provided by operating activities and borrowings under PVR’s revolving credit facility. Borrowings under PVR’s revolving credit facility funded $52.0 million of the capital expenditures in the six months ended June 30, 2007, while cash provided by operating activities funded $17.8 million of the capital expenditures in the six months ended June 30, 2007. PVR’s distributions to partners increased to $43.0 million in the six months ended June 30, 2007 from $31.0 million in the six months ended June 30, 2006 because PVR increased the quarterly unit distribution from $0.35 per unit to $0.41 per unit.

PVR borrowed $57.0 million, net of repayments, under its revolving credit facility in the six months ended June 30, 2007, compared to borrowings, net of repayments, of $61.5 million in the six months ended June 30, 2006. Funds from the borrowings were primarily used for capital expenditures.

Long-Term Debt

As of June 30, 2007, we had no outstanding borrowings other than the borrowings of PVR discussed below, which are included in our condensed consolidated financial statements.

As of June 30, 2007, PVR had outstanding borrowings of $263.3 million, consisting of $205.2 million borrowed under its revolving credit facility and $58.1 million of senior unsecured notes (the “Notes”). The current portion of the Notes as of June 30, 2007 was $11.8 million.

PVR Revolving Credit Facility. As of June 30, 2007, PVR had $205.2 million outstanding under its $300 million unsecured revolving credit facility (the “PVR Revolver”) that matures in December 2011. The PVR Revolver is available to PVR for general purposes, including working capital, capital expenditures and acquisitions, and includes a $10 million sublimit for the issuance of letters of credit. PVR had outstanding letters of credit of $1.6 million as of June 30, 2007. In the six months ended June 30, 2007, PVR incurred commitment fees of $0.2 million on the unused portion of the PVR Revolver. PVR has a one-time option to expand the PVR Revolver by $150 million upon receipt by the credit facility’s administrative agent of commitments from one or more lenders. The interest rate under the PVR Revolver fluctuates based on its ratio of total indebtedness to EBITDA. Interest is payable at a base rate plus an applicable margin of up to 0.75% if PVR selects the base rate borrowing option under the PVR Revolver or at a rate derived from the London Inter Bank Offering Rate (“LIBOR”) plus an applicable margin ranging from 0.75% to 1.75% if PVR selects the LIBOR-based borrowing option.

The financial covenants under the PVR Revolver require PVR to not exceed specified debt-to-consolidated EBITDA and consolidated EBITDA-to-interest expense ratios. At the current $300 million limit on the PVR Revolver, and given PVR’s outstanding balance of $205.2 million, net of $1.6 million of letters of credit, PVR could borrow up to $93.2 million without exercising its one-time option to expand the PVR Revolver. The PVR Revolver prohibits PVR from making distributions to its partners if any potential default, or event of default, as defined in the PVR Revolver, occurs or would result from the distributions. In addition, the PVR Revolver contains various covenants that limit, among other things, PVR’s ability to incur indebtedness, grant liens, make certain loans, acquisitions and investments, make any material change to the nature of its business, acquire another company or enter into a merger or sale of assets, including the sale or transfer of interests in PVR’s subsidiaries. As of June 30, 2007, PVR was in compliance with all of its covenants under the PVR Revolver.

PVR Senior Unsecured Notes. As of June 30, 2007, PVR owed $69.9 million under the Notes. The Notes bear interest at a fixed rate of 6.02% and mature in March 2013, with semi-annual principal and interest payments. The Notes are equal in right of payment with all of PVR’s other unsecured indebtedness, including the PVR Revolver. The Notes require PVR to obtain an annual confirmation of its credit rating, with a 1.00% increase in the interest rate payable on the Notes in the event PVR’s credit rating falls below investment grade. In March 2007, PVR’s investment grade credit rating was confirmed by Dominion Bond Rating Services. The Notes contain various covenants similar to those contained in the PVR Revolver. As of June 30, 2007, PVR was in compliance with all of its covenants under the Notes.

PVR Interest Rate Swaps. In September 2005, PVR entered into interest rate swap agreements (the “PVR Revolver Swaps”) with notional amounts totaling $60 million to establish fixed rates on the LIBOR-based portion of the outstanding balance of the PVR Revolver until March 2010. PVR pays a weighted average fixed rate of 4.22% on the notional amount plus the applicable margin, and the counterparties pay a variable rate equal to the three-month LIBOR. Settlements on the PVR Revolver Swaps are recorded as interest expense. The PVR Revolver Swaps were designated as cash flow hedges. Accordingly, the effective portion of the change in the fair value of the swap transactions is recorded each period in other comprehensive income. The ineffective portion of the change in fair value, if any, is recorded to current period earnings in interest expense. After considering the applicable margin of 0.75% in effect as June 30, 2007, the total interest rate on the $60 million portion of PVR Revolver borrowings covered by the PVR Revolver Swaps was 4.97% at June 30, 2007.

Future Capital Needs and Commitments

Currently, PVG has no capital requirements. In the future, we may decide to facilitate PVR acquisitions by providing additional debt or equity to PVR.

Part of PVR’s strategy is to make acquisitions and other capital expenditures which increase cash available for distribution to its unitholders. PVR’s ability to make these acquisitions in the future will depend in part on the availability of debt financing and on its ability to periodically use equity financing through the issuance of new common units, which will depend on various factors, including prevailing market conditions, interest rates and its financial condition and credit rating at the time. Including property acquisitions completed to date, PVR anticipates making capital expenditures in 2007 of approximately $54 million to $56 million for coal reserve acquisitions, coal services projects and other property and equipment and approximately $48 million to $52 million for natural gas midstream system expansion projects and maintenance capital expenditures. PVR intends to fund these capital expenditures with a combination of cash flows provided by operating activities and borrowings under the PVR Revolver. PVR makes quarterly cash distributions of its available cash, generally defined as all of its cash and cash equivalents on hand at the end of each quarter less cash reserves. PVR believes that it will continue to have adequate liquidity to fund future recurring operating and investing activities. Short-term cash requirements, such as operating expenses and quarterly distributions to PVR’s general partner and unitholders, are expected to be funded through operating cash flows. Long-term cash requirements for asset acquisitions are expected to be funded by several sources, including cash flows from operating activities, borrowings under credit facilities and the issuance of additional equity and debt securities.

Results of Operations

The following table sets forth a summary of certain consolidated financial data for the periods indicated:

Selected Financial Data—Consolidated


	Three Months Ended June 30,				Six Months Ended June 30,
	2007		2006		2007		2006
	(in thousands, except per unit data)				(in thousands except per unit data)
Revenues	$	144,144	$	123,463	$	268,344	$	258,627
Expenses		117,308		94,175		219,930		211,093

Operating income	$	26,836	$	29,288	$	48,414	$	47,534

Net income	$	8,301	$	5,461	$	16,021	$	8,912
Net income per limited partner unit, basic and diluted	$	0.21	$	0.17	$	0.41	$	0.28
Cash flows provided by operating activities	$	33,545	$	36,164	$	56,172	$	48,437

Operating income decreased in the three months ended June 30, 2007 compared to the same period in 2006 primarily due to a $0.3 million decrease in gross processing margin, a $1.4 million increase in operating expenses, a $1.2 million increase in general and administrative expenses and a $1.0 million increase in depreciation, depletion and amortization (“DD&A”) expenses. Operating income increased in the six months ended June 30, 2007 compared to the same period in 2006 primarily due to a $2.4 million increase in coal royalty revenues and a $4.7 million increase in gross processing margin, partially offset by a $3.4 million increase in operating expenses.

Net income increased in the three months ended June 30, 2007 compared to the same period in 2006 primarily due to a $4.4 million decrease in derivative losses and a $0.8 million decrease in interest expense, partially offset by the decrease in operating income. Net income increased in the six months ended June 30, 2007 compared to the same period in 2006 primarily due to a $7.9 million decrease in derivative losses and a $1.3 million decrease in interest expense.

The assets, liabilities and earnings of PVR are fully consolidated in our financial statements, with the public unitholders’ interest (48%, after the effect of incentive distribution rights, as of June 30, 2007) reflected as minority interest in our financial statements.

PVR Coal Segment

Three Months Ended June 30, 2007 Compared to Three Months Ended June 30, 2006

The following table sets forth a summary of certain financial and other data for PVR’s coal segment and the percentage change for the periods indicated:


	Three Months Ended June 30,				% Change
	2007		2006		% Change
	(in thousands, except as noted)
Financial Highlights

Revenues
Coal royalties	$	24,029	$	24,254	(1	)%
Coal services		2,092		1,404	49	%
Other		2,289		2,240	2	%

Total revenues		28,410		27,898	2	%

Expenses
Operating		2,514		1,253	101	%
Taxes other than income		267		101	164	%
General and administrative		2,743		2,468	11	%
Depreciation, depletion and amortization		5,320		4,747	12	%

Total expenses		10,844		8,569	27	%

Operating income	$	17,566	$	19,329	(9	)%

Operating Statistics
Royalty coal tons produced by lessees (tons in thousands)		8,060		7,966	1	%
Average royalty per ton ($/ton)	$	2.98	$	3.04	(2	)%

Revenues. Coal royalty revenues remained relatively constant from the three months ended June 30, 2006 to the same period in 2007. Tons produced by PVR’s lessees increased from 8.0 million tons in the three months ended June 30, 2006 to 8.1 million tons in the same period of 2007, and PVR’s average gross royalty per ton decreased from $3.04 for the three months ended June 30, 2006 to $2.98 for the same period in 2007. The decrease in average royalty per ton was primarily due to a decrease in the price of coal. Generally, as coal prices change, PVR’s average royalty per ton also changes because the majority of PVR’s lessees pay royalties based on the gross sales prices of the coal mined. Most of PVR’s coal is sold by its lessees under contracts with a duration of one year or more; therefore, changes to PVR’s average royalty occurs as its lessees’ contracts are renegotiated. The coal reserves in West Virginia that PVR acquired in May 2006 resulted in $1.3 million of coal royalty revenues in the three months ended June 30, 2007.

Coal services revenues increased to $2.1 million for the three months ended June 30, 2007 from $1.4 million for the same period in 2006, or 49%, primarily due to the completed construction of a coal services facility in Knott County, Kentucky, which began operations in October 2006. This facility contributed $0.4 million to coal services revenues in the three months ended June 30, 2007. We believe these types of fee-based infrastructure assets provide good investment and cash flow opportunities, and we continue to look for additional investments of this type, as well as other primarily fee-based assets.

The following table summarizes coal production and coal royalty revenues by property:


	Coal Production		Coal Royalty Revenues
	Three Months Ended June 30		Three Months Ended June 30
Property	2007	2006	2007		2006
	(tons in thousands)		(in thousands)
Central Appalachia	5,018	5,041	$	18,274	$	19,253
Northern Appalachia	1,080	1,340		1,654		1,985
Illinois Basin	502	625		1,180		1,210
San Juan Basin	1,460	960		2,921		1,806

Total	8,060	7,966	$	24,029	$	24,254

Expenses. Operating expenses increased to $2.5 million for the three months ended June 30, 2007 from $1.3 million for the same period in 2006, or 101%, primarily due to increased production on PVR’s subleased Central Appalachian properties. Fluctuations in production on subleased properties have a direct impact on royalty expense. General and administrative expenses increased by 11% to $2.7 million primarily due to increased payroll costs. DD&A expense increased by 12% to $5.3 million primarily due to the completed construction of a coal services facility in Knott County, Kentucky, which began operations in October 2006.

Six Months Ended June 30, 2007 Compared to Six Months Ended June 30, 2006

The following table sets forth a summary of certain financial and other data for PVR’s coal segment and the percentage change for the periods indicated:


	Six Months Ended June 30,				% Change
	2007		2006		% Change
	(in thousands, except as noted)
Financial Highlights

Revenues
Coal royalties	$	49,029	$	46,676	5	%
Coal services		3,693		2,830	30	%
Other		4,172		3,720	12	%

Total revenues		56,894		53,226	7	%

Expenses
Operating		4,669		2,221	110	%
Taxes other than income		590		411	44	%
General and administrative		5,359		4,699	14	%
Depreciation, depletion and amortization		10,810		9,499	14	%

Total expenses		21,428		16,830	27	%

Operating income	$	35,466	$	36,396	(3	)%

Operating Statistics
Royalty coal tons produced by lessees (tons in thousands)		16,344		15,686	4	%
Average royalty per ton ($/ton)	$	3.00	$	2.98	1	%

Revenues. Coal royalty revenues increased to $49.0 million for the six months ended June 30, 2007 from $46.7 million for the same period in 2006, or 5%, due to an increase in production by PVR’s lessees and an increase in average royalty per ton. Tons produced by PVR’s lessees increased from 15.7 million tons in the six months ended June 30, 2006 to 16.3 million tons in the same period in 2007, and PVR’s average gross royalty per ton increased

from $2.98 for the six months ended June 30, 2006 to $3.00 for the same period in 2007. The increase in the average royalty per ton was primarily due to an increase in the price of coal. Generally, as coal prices change, PVR’s average royalty per ton also changes because the majority of PVR’s lessees pay royalties based on the gross sales prices of the coal mined. Most of PVR’s coal is sold by its lessees under contracts with a duration of one year or more; therefore, changes to PVR’s average royalty occur as its lessees’ contracts are renegotiated. The coal reserves in West Virginia that PVR acquired in May 2006 resulted in $2.8 million of coal royalty revenues in the six months ended June 30, 2007.

Coal services revenues increased to $3.7 million for the six months ended June 30, 2007 from $2.8 million for the same period in 2006, or 30%, primarily due to the completed construction of a coal services facility in Knott County, Kentucky, which began operations in October 2006. This facility contributed $0.8 million to coal services revenues in the six months ended June 30, 2007. We believe these types of fee-based infrastructure assets provide good investment and cash flow opportunities, and we continue to look for additional investments of this type, as well as other primarily fee-based assets.

The following table summarizes coal production and coal royalty revenues by property:


	Coal Production		Coal Royalty Revenues
	Six Months Ended June 30		Six Months Ended June 30
Property	2007	2006	2007		2006
	(tons in thousands)		(in thousands)
Central Appalachia	9,975	9,439	$	37,184	$	35,921
Northern Appalachia	2,450	2,624		3,757		3,853
Illinois Basin	1,120	1,341		2,487		2,611
San Juan Basin	2,799	2,282		5,601		4,291

Total	16,344	15,686	$	49,029	$	46,676

Expenses. Operating expenses increased to $4.7 million for the six months ended June 30, 2007 from $2.2 million for the same period in 2006, or 110%, primarily due to production on PVR’s subleased Central Appalachian properties. Fluctuations in production on subleased properties have a direct impact on royalty expense. General and administrative expenses increased by 14% to $5.4 million primarily due to increased payroll costs. DD&A expense increased by 14% to $10.8 million primarily due to the completed construction of a coal services facility in Knott County, Kentucky, which began operations in October 2006.

PVR Natural Gas Midstream Segment

Three Months Ended June 30, 2007 Compared to Three Months Ended June 30, 2006

The following table sets forth a summary of certain financial and other data for PVR’s natural gas midstream segment and the percentage change for the periods indicated:


	Three Months Ended June 30,				% Change
	2007		2006		% Change
	(in thousands)
Financial Highlights

Revenues
Residue gas	$	69,383	$	58,158	19	%
Natural gas liquids		41,162		34,191	20	%
Condensate		3,158		2,570	23	%
Gathering and transportation fees		704		431	63	%

Total natural gas midstream revenues		114,407		95,350	20	%
Producer services		1,327		215	517	%

Total revenues		115,734		95,565	21	%

Expenses
Cost of midstream gas purchased		95,077		75,692	26	%
Operating		2,983		2,842	5	%
Taxes other than income		336		337	(0	)%
General and administrative		3,020		2,665	13	%
Depreciation and amortization		4,502		4,069	11	%

Total operating expenses		105,918		85,605	24	%

Operating income	$	9,816	$	9,960	(1	)%

Operating Statistics
System throughput volumes (MMcf)		16,870		14,466	17	%
Gross processing margin	$	19,330	$	19,658	(2	)%

Revenues. Natural gas midstream revenues increased to $114.4 million for the three months ended June 30, 2007 from $95.4 million for the same period in 2006, or 20%, due to a more favorable pricing environment combined with increased system throughput volumes. Revenues included residue gas sold from processing plants after NGLs were removed, NGLs sold after being removed from system throughput volumes received, condensate collected and sold, gathering and other fees primarily from natural gas volumes connected to our gas processing plants and the purchase and resale of natural gas not connected to our gathering systems and processing plants.

Producer services revenues increased by $1.1 million during the three months ended June 30, 2007 as compared to same period in 2006 due to an increase in marketed gas volumes.

Expenses. Operating costs and expenses primarily consisted of the cost of midstream gas purchased and also included operating expenses, taxes other than income, general and administrative expenses and depreciation and amortization.

The gross processing margin for PVR’s natural gas midstream operations remained relatively constant from the three months ended June 30, 2006 to the same period in 2007. System throughput volumes at PVR’s gas processing plants and gathering systems increased to 185 MMcfd for the three months ended June 30, 2007 from 159 MMcfd for the same period in 2006, an increase of 26 MMcfd, or 16%, primarily due to higher average daily system throughput volumes resulting from pipeline acquisitions, successful drilling of local producers and expansion of PVR’s current facilities. PVR’s natural gas midstream business generates revenues primarily from gas purchase and processing contracts with natural gas producers and from fees charged for gathering natural gas volumes and providing other related services. During the three months ended June 30, 2007, PVR’s natural gas midstream business generated a majority of its gross margin from contractual arrangements under which its margin is exposed to increases and decreases in the price of natural gas and NGLs. As part of PVR’s risk management strategy, PVR uses derivative financial instruments to economically hedge NGLs sold and natural gas purchased.

The following table shows a summary of the effects of derivative activities on natural gas midstream processing margin:


	Three Months Ended June 30,
	2007			2006
	(in thousands)
Gross processing margin, as reported	$	19,330		$	19,658
Derivatives (gains) losses included in gross processing margin		1,285			711

Gross processing margin before impact of derivatives		20,615			20,369
Cash settlements on derivatives		(2,189	)		(5,139	)

Gross processing margin, adjusted for derivatives	$	18,426		$	15,230

Depreciation and amortization expenses increased primarily due to increased expenses associated with the pipeline obtained as part of a June 2006 acquisition.

Six Months Ended June 30, 2007 Compared to Six Months Ended June 30, 2006

The following table sets forth a summary of certain financial and other data for PVR’s natural gas midstream segment and the percentage change for the periods indicated:


	Six Months Ended June 30,				% Change
	2007		2006		% Change
	(in thousands)
Financial Highlights

Revenues
Residue gas	$	129,064	$	136,688	(6	)%
Natural gas liquids		73,150		62,228	18	%
Condensate		6,073		4,842	25	%
Gathering and transportation fees		1,438		773	86	%

Total natural gas midstream revenues		209,725		204,531	3	%
Producer services		1,725		870	98	%

Total revenues		211,450		205,401	3	%

Expenses
Cost of midstream gas purchased		174,808		174,343	0	%
Operating		6,342		5,351	19	%
Taxes other than income		856		725	18	%
General and administrative		6,043		5,705	6	%
Depreciation and amortization		9,145		8,138	12	%

Total operating expenses		197,194		194,262	2	%

Operating income	$	14,256	$	11,139	28	%

Operating Statistics
System throughput volumes (MMcf)		32,919		28,648	15	%
Gross processing margin	$	34,917	$	30,188	16	%

Revenues. Natural gas midstream revenues increased to $209.7 million for the six months ended June 30, 2007 from $204.5 million for the same period in 2006, or 3%, due to a more favorable pricing environment combined with increased system throughput volumes. Revenues included residue gas sold from processing plants after NGLs were removed, NGLs sold after being removed from system throughput volumes received, condensate collected and sold, gathering and other fees primarily from natural gas volumes connected to our gas processing plants and the purchase and resale of natural gas not connected to our gathering systems and processing plants.

Cost of midstream gas purchased consisted of amounts payable to third-party producers for natural gas purchased under percentage of proceeds and keep-whole contracts. Cost of midstream gas purchased increased slightly primarily due to an increase in system throughput volumes. This increase in system throughput volumes was partially offset by a $4.6 million non-cash charge recorded to reserves in the six months ended June 30, 2006 for amounts related to balances assumed as part of the acquisition of our natural gas midstream business in 2005.

The gross processing margin for PVR’s natural gas midstream operations increased 16%, from $30.2 million in the six months ended June 30, 2006 to $34.9 million in the six months ended June 30, 2007. This increase was due primarily to a more favorable pricing environment in the six months ended 2007 compared to the same period in

2006. System throughput volumes at PVR’s gas processing plants and gathering systems increased to 182 MMcfd for the six months ended June 30, 2007 from 158 in the same period in 2006, an increase of 24 MMcfd, or 15%, primarily due to pipeline acquisitions, successful drilling of local producers and expansion of our current facilities. PVR’s natural gas midstream business generates revenues primarily from gas purchase and processing contracts with natural gas producers and from fees charged for gathering natural gas volumes and providing other related services. During the six months ended June 30, 2007, PVR’s natural gas midstream business generated a majority of its gross margin from contractual arrangements under which its margin is exposed to increases and decreases in the price of natural gas and NGLs. As part of PVR’s risk management strategy, PVR uses derivative financial instruments to economically hedge NGLs sold and natural gas purchased.

The following table shows a summary of the effects of derivative activities on natural gas midstream processing margin:


	Six Months Ended June 30,
	2007			2006
	(in thousands)
Gross processing margin, as reported	$	34,917		$	30,188
Derivatives (gains) losses included in gross processing margin		2,128			450

Gross processing margin before impact of derivatives		37,045			30,638
Cash settlements on derivatives		(4,261	)		(8,061	)

Gross processing margin, adjusted for derivatives	$	32,784		$	22,577

Depreciation and amortization expenses increased primarily due to increased expenses associated with the pipeline obtained as part of a June 2006 acquisition.

Corporate and Other

Corporate and other results primarily consist of oversight and administrative functions.

General and Administrative Expenses. We had general and administrative expenses other than from the coal and natural gas midstream segments of $0.5 million and $1.3 million for the three months and six months ended June 30, 2007. These expenses consisting primarily of salaries and other professional services attributable to our overhead functions.

Interest Expense. Interest expense decreased by $1.3 million from $8.5 million for the six months ended June 30, 2006 to $7.2 million for the same period in 2007, or 15%. Interest expense decreased by $0.8 million from $4.4 million for the three months ended June 30, 2006 to $3.6 for the same period in 2007, or 18%. The decreases in both periods were primarily due to PVR making a $114.6 million principal payment on its revolving credit facility in December 2006.

Derivatives. Derivative losses decreased to $7.6 million for the three months ended June 30, 2007 from $11.9 million for the same period in 2006, or 36%. Derivative losses decreased to $10.2 million for the six months ended June 30, 2007 from $18.1 million for the same period in 2006, or 44%. The decreases in both periods were primarily due to mark-to-market adjustments.

Minority Interest. Minority interest represents PVR’s net income allocated to the limited partner units owned by the public. For the three months ended June 30, 2007 and 2006, minority interest reduced our consolidated income from operations by $7.8 million. For the six months ended June 30, 2007 and 2006, minority interest reduced our consolidated income from operations by $15.9 million and $12.6 million. The increase in minority interest was due primarily to the increase in PVR’s net income from $21.6 million in the six months ended June 30, 2006 to $33.0 million in the same period in 2007.

Summary of Critical Accounting Policies and Estimates

The process of preparing financial statements in accordance with accounting principles generally accepted in the United States of America requires our management to make estimates and judgments regarding certain items and transactions. It is possible that materially different amounts could be recorded if these estimates and judgments change or if the actual results differ from these estimates and judgments. We consider the following to be the most critical accounting policies which involve the judgment of our management.

Natural Gas Midstream Revenues

Revenues from the sale of NGLs and residue gas are recognized when the NGLs and residue gas produced at PVR’s gas processing plants are sold. Gathering and transportation revenues are recognized based upon actual volumes delivered. Due to the time needed to gather information from various purchasers and measurement locations and then calculate volumes delivered, the collection of natural gas midstream revenues may take up to 30 days following the month of production. Therefore, accruals for revenues and accounts receivable and the related cost of midstream gas purchased and accounts payable are made based on estimates of natural gas purchased and NGLs and natural gas sold, and our financial results include estimates of production and revenues for the period of actual production. Any differences, which we do not expect to be significant, between the actual amounts ultimately received or paid and the original estimates are recorded in the period they become finalized.

Coal Royalty Revenues

Coal royalty revenues are recognized on the basis of tons of coal sold by PVR’s lessees and the corresponding revenues from those sales. Since PVR does not operate any coal mines, it does not have access to actual production and revenues information until approximately 30 days following the month of production. Therefore, PVR’s financial results include estimated revenues and accounts receivable for the month of production. Any differences, which we do not expect to be significant, between the actual amounts ultimately received and the original estimates are recorded in the period they become finalized.

Derivative Activities

PVR historically has entered into derivative financial instruments that would qualify for hedge accounting under Statement of Financial Accounting Standards (“SFAS”) No. 133, Accounting for Derivative Instruments and Hedging Activities. Hedge accounting affects the timing of revenue recognition and cost of midstream gas purchased in our condensed consolidated statements of income, as a majority of the gain or loss from a contract qualifying as a cash flow hedge is deferred until the related hedged transaction settles. Because during the first quarter of 2006 PVR’s natural gas derivatives and a large portion of PVR’s NGL derivatives no longer qualified for hedge accounting and to increase clarity in its condensed consolidated financial statements, PVR elected to discontinue hedge accounting prospectively for its remaining and future commodity derivatives beginning May 1, 2006. Consequently, from that date forward, PVR began recognizing mark-to-market gains and losses in earnings currently, rather than deferring such amounts in accumulated other comprehensive income (partners’ capital). Because PVR no longer uses hedge accounting for its commodity derivatives, we could experience significant changes in the estimate of derivative gain or loss recognized in revenues and cost of midstream gas purchased due to swings in the value of these contracts. These fluctuations could be significant in a volatile pricing environment.

The net mark-to-market loss on PVR’s outstanding derivatives at April 30, 2006, which was included in accumulated other comprehensive income (“AOCI”), will be reported in earnings through 2008 as the original hedged transactions settle. In the natural gas midstream segment, PVR expects to recognize hedging losses of $2.5 million for the remainder of 2007 and $5.5 million for 2008 for amounts currently included in AOCI. This change in reporting will have no impact on our reported cash flows, although future results of operations will be affected by the potential volatility of mark-to-market gains and losses which fluctuate with changes in NGL, oil and gas prices.

Depletion

Coal properties are depleted on an area-by-area basis at a rate based on the cost of the mineral properties and the number of tons of estimated proven and probable coal reserves contained therein. Proven and probable coal reserves have been estimated by PVR’s own geologists and outside consultants. PVR’s estimates of coal reserves are updated annually and may result in adjustments to coal reserves and depletion rates that are recognized prospectively.

Goodwill

Under SFAS No. 141, Business Combinations, and SFAS No. 142, Goodwill and Other Intangible Assets, goodwill recorded in connection with a business combination is not amortized, but tested for impairment at least annually. Accordingly, we do not amortize goodwill. We test goodwill for impairment during the fourth quarter of each fiscal year.

Intangibles

Intangible assets are primarily associated with assumed contracts, customer relationships and rights-of-way. These intangible assets are amortized over periods of up to 15 years, the period in which benefits are derived from the contracts, relationships and rights-of-way, and are reviewed for impairment under SFAS No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets.

Environmental Matters

To dispose of mining overburden generated by their surface mining activities, PVR’s lessees need to obtain government approvals, including Federal Clean Water Act (“CWA”) Section 404 permits to construct valley fills and sediment control ponds. Two CWA Section 404 permits issued to Alex Energy, Inc. (“Alex Energy”), one of PVR’s surface coal mine lessees in West Virginia, were recently challenged in a lawsuit, Ohio Valley Environmental Coalition (“OVEC”) v. United States Army Corps of Engineers. On March 23, 2007, the U.S. District Court for the Southern District of West Virginia rescinded and remanded the permit authorizing several valley fills and sediment ponds that may be constructed at the Republic No. 2 Mine and enjoined Alex Energy from taking any further actions under this permit. The district court has yet to rule on whether the other CWA Section 404 permit for the construction of valley fills and associated sediment ponds at the Republic No. 1 Mine was also invalidly issued. Although portions of the Republic No. 2 Mine continue to operate based on a subsequent order allowing the mine to fully utilize and complete some of its partially constructed valley fills, the construction of new valley fills at other portions of the Republic No. 2 Mine is enjoined pending a final outcome of this litigation. On June 13, 2007, the district court also issued a declaratory judgment indicating that the mining companies subject to the OVEC decision may also be required to obtain new, separate CWA Section 402 permit authorizations for the stream segments located between the toes of their valley fills and their respective sediment pond embankments.

The district court’s March 23, 2007 decision is currently on appeal to the U.S. Court of Appeals for the Fourth Circuit. While PVR is still reviewing the district court’s ruling, its lessees may not be able to obtain or may experience delays in securing additional CWA Section 404 permits for surface mining operations. Unless the OVEC decision is overturned or further limited in subsequent proceedings, the ruling and its collateral consequences could ultimately have an adverse effect on PVR’s coal royalty revenues.

Recent Accounting Pronouncements

See Note 2 in the Notes to Condensed Consolidated Financial Statements for a description of recent accounting pronouncements.

Forward-Looking Statements

Certain statements contained herein that are not descriptions of historical facts are “forward-looking” statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended ( the “Exchange Act”). Because such statements include risks, uncertainties and contingencies, actual results may differ materially from those expressed or implied by such forward-looking statements. These risks, uncertainties and contingencies include, but are not limited to, the following:

•

PVR’s ability to generate sufficient cash from its natural gas midstream and coal businesses to pay the minimum quarterly distribution to its general partner and PVR’s unitholders;

•

energy prices generally and specifically, the price of natural gas, NGLs and coal;

•

the relationship between natural gas and NGL prices;

•

the price of coal and its comparison to the price of natural gas;

•

the volatility of commodity prices for coal, natural gas and NGLs;

•

the projected demand for coal, natural gas and NGLs;

•

the projected supply of coal, natural gas and NGLs;

•

PVR’s ability to successfully manage PVR’s relatively new natural gas midstream business;

•

PVR’s ability to acquire new coal reserves or natural gas midstream assets on satisfactory terms;

•

the price for which PVR can acquire coal reserves;

•

PVR’s ability to continually find and contract for new sources of natural gas supply;

•

PVR’s ability to retain existing or acquire new natural gas midstream customers;

•

PVR’s ability to lease new and existing coal reserves;

•

the ability of PVR’s lessees to produce sufficient quantities of coal on an economic basis from PVR’s reserves;

•

the ability of PVR’s lessees to obtain favorable contracts for coal produced from our reserves;

•

competition among producers in the coal industry generally and among natural gas midstream companies;

•

PVR’s exposure to the credit risk of its coal lessees and natural gas midstream customers;

•

the extent to which the amount and quality of PVR’s actual production differ from its estimated recoverable proved coal reserves;

•

hazards or operating risks incidental to natural gas midstream operations;

•

unanticipated geological problems;

•

the dependence of PVR’s natural gas midstream business on having connections to third party pipelines;

•

the availability of production equipment and materials;

•

the occurrence of unusual weather or operating conditions including force majeure events;

•

the failure of PVR’s infrastructure and PVR’s lessees’ mining equipment or processes to operate in accordance with specifications or expectations;

•

delays in anticipated start-up dates of PVR’s lessees’ mining operations and related coal infrastructure projects;

•

environmental risks affecting the mining of coal reserves or the production, gathering and processing of natural gas;

•

the timing of receipt of necessary governmental permits by PVR or PVR’s lessees;

•

the risks associated with having or not having price risk management programs;

•

labor relations and costs;

•

accidents;

•

changes in governmental regulation or enforcement practices, especially with respect to environmental, health and safety matters, including with respect to emissions levels applicable to coal-burning power generators;

•

uncertainties relating to the outcome of current and future litigation regarding mine permitting;

•

risks and uncertainties relating to general domestic and international economic (including inflation and interest rates) and political conditions (including the impact of potential terrorist attacks);

•

the experience and financial condition of PVR’s coal lessees and natural gas midstream customers, including their ability to satisfy their royalty, environmental, reclamation and other obligations to PVR and others;

•

PVR’s ability to expand its natural gas midstream business by constructing new gathering systems, pipelines and processing facilities on an economic basis and in a timely manner;

•

coal handling joint venture operations;

•

changes in financial market conditions; and

•

other risks set forth in Item 1A, “Risk Factors,” of our Annual Report on Form 10-K for the year ended December 31, 2006.

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, 2006. Many of the factors that will determine our future results are beyond the ability of management to control or predict. 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.

Item 3

Quantitative and Qualitative Disclosures About Market Risk

Market risk is the risk of loss arising from adverse changes in market rates and prices. The principal market risks to which PVR is exposed are NGL, crude oil, natural gas and coal price risks and interest rate risk.

PVR is also indirectly exposed to the credit risk of its customers and lessees. If its customers or lessees become financially insolvent, they may not be able to continue to operate or meet their payment obligations.

Price Risk Management

PVR’s price risk management program permits the utilization of derivative financial instruments (such as futures, forwards, option contracts and swaps) to seek to mitigate the price risks associated with fluctuations in natural gas, NGL and crude oil prices as they relate to PVR’s natural gas midstream business. The derivative financial instruments are placed with major financial institutions that PVR believes are of minimum credit risk. The fair value of PVR’s price risk management assets is significantly affected by fluctuations in the prices of natural gas, NGLs and crude oil.

For the six months ended June 30, 2007, PVR reported a net $10.2 million derivative loss for mark-to-market adjustments. Because during the first quarter of 2006 PVR’s natural gas derivatives and a large portion of PVR’s NGL derivatives no longer qualified for hedge accounting and to increase clarity in its condensed consolidated financial statements, PVR elected to discontinue hedge accounting prospectively for its remaining and future commodity derivatives beginning May 1, 2006. Consequently, from that date forward, PVR began recognizing mark-to-market gains and losses in earnings currently, rather than deferring such amounts in accumulated other comprehensive income (partners’ capital). The net mark-to-market loss on PVR’s outstanding derivatives at April 30, 2006, which was included in accumulated other comprehensive income, will be reported in future earnings through 2008 as the original hedged transactions settle. PVR expects to recognize hedging losses of $2.5 million for the remainder of 2007 and $5.5 million for 2008 related to such settlements. The discontinuation of hedge accounting will have no impact on our reported cash flows, although future results of operations will be affected by the potential volatility of mark-to-market gains and losses which fluctuate with changes in NGL, oil and gas prices. See the discussion and tables in Note 5 in the Notes to Condensed Consolidated Financial Statements for a description of PVR’s derivative program.

The following table lists PVR’s open mark-to-market derivative agreements and their fair values as of June 30, 2007:


	Average Volume Per Day	Weighted Average Price		Weighted Average Collars				Estimated Fair Value
	Average Volume Per Day	Weighted Average Price		Put		Call		Estimated Fair Value
Ethane Swaps	(in gallons)	(per gallon)						(in thousands)
Third Quarter 2007 through Fourth Quarter 2007	34,440	$	0.5050					$	(1,421	)
First Quarter 2008 through Fourth Quarter 2008	34,440	$	0.4700						(2,344	)

Propane Swaps	(in gallons)	(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	26,040	$	0.7550						(1,952	)
First Quarter 2008 through Fourth Quarter 2008	26,040	$	0.7175						(3,820	)

Crude Oil Swaps	(in barrels)	(per barrel)
Third Quarter 2007 through Fourth Quarter 2007	560	$	50.80						(2,071	)
First Quarter 2008 through Fourth Quarter 2008	560	$	49.27						(4,473	)

Natural Gas Swaps	(in MMbtu)	(per MMbtu)
Third Quarter 2007 through Fourth Quarter 2008	4,000	$	6.97						2,258

Natural Gasoline Swap/Crude Oil Swap	(in gallons / in barrels)	(per gallon / per barrel)
Third Quarter 2007 through Fourth Quarter 2007	23,520 / 560	$	1.265 / 57.12						(294	)

Ethane Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	5,000			$	0.6100	$	0.7125		(52	)

Propane Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2007	9,000			$	1.0300	$	1.1640		(72	)

Natural Gasoline Collar	(in gallons)			(per gallon)
Third Quarter 2007 through Fourth Quarter 2008	6,300			$	1.4800	$	1.6465		(380	)

Crude Oil Collar	(in barrels)			(per barrel)
First Quarter 2008 through Fourth Quarter 2008	400			$	65.00	$	75.25		(226	)

Frac Spread	(in MMbtu)	(per MMbtu)
Third Quarter 2007 through Fourth Quarter 2007	7,128	$	4.299						(2,196	)

Settlements to be paid in subsequent period									(1,026	)

Natural gas midstream segment commodity derivatives - net liability								$	(18,069	)

Interest Rate Risk

As of June 30, 2007, PVR had $205.2 million of outstanding indebtedness under the PVR Revolver, which carries a variable interest rate throughout its term. PVR entered into the PVR Revolver Swaps in September 2005 to effectively convert the interest rate on $60 million of the amount outstanding under the PVR Revolver from a LIBOR-based floating rate to a weighted average fixed rate of 4.22% plus the applicable margin. The PVR Revolver Swaps are accounted for as cash flow hedges in accordance with SFAS No. 133. A 1% increase in short-term interest rates on the floating rate debt outstanding under the PVR Revolver (net of amounts fixed through hedging transactions) at June 30, 2007 would cost PVR approximately $1.5 million in additional interest expense.

Item 4

Controls and Procedures

(a) Disclosure Controls and Procedures

Under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, we performed an evaluation of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) as of June 30, 2007. Our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports we file or submit under the Exchange Act is recorded, processed, summarized and reported accurately and on a timely basis. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that, as of June 30, 2007, such disclosure controls and procedures were effective.

(b) Changes in Internal Control over Financial Reporting

No changes were made in our internal control over financial reporting during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

In July 2007, we migrated our financial accounting and reporting system to a new enterprise resource planning (“ERP”) system. In connection with the implementation of our ERP system, we could experience control and implementation issues impacting our financial reporting. In the event that the preceding occurs, we may implement additional manual procedures to address these financial reporting issues. We will continue to monitor and test the new system as part of our evaluation of our internal control over financial reporting for 2007.

PART II. OTHER INFORMATION

Items 1, 1A, 2, 3, 4 and 5 are not applicable and have been omitted.

Item 6

Exhibits


31.1		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


		PENN VIRGINIA GP HOLDINGS, L.P.

		By: PVG GP, LLC

Date: August 2, 2007	By:	/s/ Frank A. Pici
		Frank A. Pici
		Vice President and Chief Financial Officer

Date: August 2, 2007	By:	/s/ Forrest W. McNair
		Forrest W. McNair
		Vice President and Controller

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