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Penn Virginia Resource Partners, L.P. Announces Third Quarter Results and 2005 Guidance Update; New Records Set for Quarterly Distributable Cash Flow, Operating Income and Net Income

Posted on: Wednesday, 2 November 2005, 18:00 CST

Penn Virginia Resource Partners, L.P. (NYSE:PVR) today reported its fourth consecutive quarter of record distributable cash flow. For the third quarter of 2005, distributable cash flow was $23.8 million, an increase of 72 percent over the $13.8 million reported for the same quarter of 2004 and six percent higher than the previous record of $22.4 million reported for the second quarter of 2005. Operating income was a record $22.5 million in the third quarter of 2005 as compared to $10.5 million in the same quarter of 2004. PVR also reported record net income of $22.4 million, or $1.03 per limited partner unit, for the third quarter of 2005, compared with net income of $9.1 million, or $0.50 per limited partner unit, for the third quarter of 2004. The increases in distributable cash flow, a non-GAAP measure, operating income and net income were primarily attributable to the contribution of PVR's natural gas midstream business that was acquired in the first quarter of 2005 and increased coal royalty revenues resulting from higher coal prices. In addition to those factors, net income for the third quarter of 2005 increased by $3.6 million, or $0.17 per limited partner unit, due to a non-cash, unrealized gain on derivatives resulting from the ineffectiveness of open commodity price hedges related to PVR's natural gas midstream business. A reconciliation of distributable cash flow and other non-GAAP financial measures appears in the financial tables following this news release.

In the first nine months of 2005, PVR reported distributable cash flow of $62.5 million, compared to $39.2 million reported for the same period of 2004. Net income for the first nine months of 2005 was $36.8 million, or $1.77 per limited partner unit, compared to net income of $25.7 million, or $1.40 per limited partner unit, for the first nine months of 2004. As was the case with third quarter 2005 results, the increases in the year-to-date 2005 results were primarily due to the contribution of the natural gas midstream business acquired in the first quarter of 2005 and increased coal royalty revenues resulting from higher coal prices.

Cash Distribution

PVR will pay a quarterly cash distribution covering the period July 1 through September 30, 2005 in the amount of $0.65 per unit, or an annualized rate of $2.60 per unit, on November 14, 2005 to unit holders of record as of November 3, 2005.

Coal Segment Operations

-- Third quarter 2005 operating income in the coal segment was a

record $16.6 million, or 58 percent higher than the $10.5

million reported in the third quarter of 2004. Primary reasons

for the improved operating results were as follows:

-- Coal royalty revenues were a record $22.7 million in the third

quarter of 2005, a 26 percent increase over the $18.0 million

reported in the third quarter of 2004, due primarily to a

higher average royalty per ton. The average royalty per ton

was $2.67 in the third quarter of 2005, an 18 percent increase

over the average royalty of $2.26 in the third quarter of

2004. This increase was primarily due to stronger market

conditions for coal resulting in higher prices and a greater

percentage of production from certain price-sensitive leases.

Coal production from PVR properties increased to 8.5 million

tons in the third quarter of 2005 from 8.0 million tons in the

same quarter of 2004, primarily due to production from newly

acquired properties in the western Kentucky portion of the

Illinois basin.

-- Coal services revenues increased by 18 percent to $1.3 million

in the third quarter of 2005 from $1.1 million in the third

quarter of 2004. The increase primarily related to increased

equity earnings from the coal handling joint venture in which

PVR acquired an interest in July 2004.

-- Other revenues increased to $1.9 million in the third quarter

of 2005 from $0.3 million in the third quarter of 2004. The

increase was primarily due to additional coal

transportation-related fees and oil and gas royalty revenues

as a result of April 2005 acquisitions in Appalachia.

-- Operating expenses increased by six percent to $1.9 million in

the third quarter of 2005 from $1.8 million in the third

quarter of 2004 due to increased production from subleased

properties.

-- General and administrative expenses decreased to $1.9 million

in the third quarter of 2005 from $2.1 million in the third

quarter of 2004, primarily attributable to cost sharing of

corporate administrative expenses with the new natural gas

midstream segment.

-- Non-cash depreciation, depletion and amortization (DD&A)

expense increased to $5.3 million in the third quarter of 2005

from $4.8 million in the same quarter of last year, primarily

as a result of higher production.

Midstream Segment Operations

Third quarter 2005 operating income in the natural gas midstream segment acquired in March 2005 from Cantera Gas Resources, LLC (the "Cantera Acquisition") was $5.9 million, consisting of the following:

-- Natural gas midstream revenues were $103.9 million and

included revenues from the sale of residue gas, natural gas

liquids and condensate and gathering and transportation fees.

Inlet volumes at the midstream segment's gas processing plants

and gathering systems were approximately 11.6 billion cubic

feet during the third quarter, or approximately 126 million

cubic feet per day.

-- Cost of gas purchased of $89.6 million consisted of amounts

payable to third-party producers for gas purchased under

percentage of proceeds and keep-whole contracts. Gross

processing margin, consisting of midstream revenues minus the

cost of gas purchased, was $14.2 million, or $1.23 per

thousand cubic feet of plant inlet gas.

-- Operating costs directly associated with the operations of the

natural gas midstream segment were $2.7 million for the third

quarter of 2005.

-- DD&A expense of $3.9 million for the third quarter of 2005

included $1.2 million of amortization of intangible costs and

$2.7 million of depreciation on property, plant and equipment

related to the Cantera Acquisition.

Capital Resources

As of September 30, 2005, PVR's outstanding borrowings were $257.9 million, including $8.1 million of senior unsecured notes classified as current portion of long-term debt. Interest expense increased from $1.7 million in the third quarter of 2004 to $3.9 million for the third quarter of 2005 as a result of interest on increased borrowings related to the Cantera Acquisition and coal property acquisitions in 2005.

In July 2005, PVR increased the size of its revolving credit facility from $150 million to $300 million. The amended credit facility was used to fund the $62 million acquisition of coal property in the western Kentucky portion of the Illinois basin, which closed on July 20, 2005.

In September 2005, PVR entered into interest rate swap agreements with notional amounts totaling $60 million to establish fixed rates of approximately six percent on that portion of the outstanding balance of PVR's revolving credit facility until March 2010.

Management Comment

A. James Dearlove, Chief Executive Officer of Penn Virginia Resource Partners, L.P., said, "After setting record levels of distributable cash flow, operating and net income in the second quarter of 2005, PVR set new record levels for all three measures in the third quarter. These results indicate the success of our growth strategy in both our coal land management and natural gas midstream businesses.

"In the Partnership's coal segment, coal royalty revenues increased 13 percent from the second quarter of 2005 to the third quarter, driven primarily by royalties from the Illinois basin property acquired in July 2005 and an increase in royalties from a longwall mine on a subleased property in West Virginia. The strong pricing in the coal market is expected to result in record levels of revenues and operating income in this segment for 2005.

"PVR's natural gas midstream gathering and processing segment has continued to outperform our acquisition model through its first seven months of operations as part of PVR. Third quarter 2005 plant and gathering system inlet volumes remained steady at 126 million cubic feet per day and the strong commodity pricing environment resulted in an increase in gross processing margins from $1.10 per Mcf of inlet volume to in 2005's second quarter to $1.23 per Mcf in the third quarter.

"We continue to pursue our strategy of expanding both our coal and midstream businesses by making appropriate acquisitions and facilitating organic growth. In keeping with this strategy, we have identified a number of growth opportunities to expand and improve operations in our core and other areas."

Guidance Update for 2005

See the 2005 Guidance Table included in this release for guidance estimates for the fourth quarter and full year 2005. These estimates, including capital expenditure plans, are meant to provide guidance only and are subject to revision as PVR's operating environment changes.

Conference Call

As announced in our October 7, 2005 press release, a conference call and webcast, at which management will discuss third quarter 2005 results and the outlook for the remainder of 2005 is scheduled for Thursday, November 3, 2005, at 1:00 p.m. EST. Prepared remarks by A. James Dearlove, Chief Executive Officer, will be followed by a question and answer period. Investors and analysts may participate via phone by dialing 1-877-407-9205 five to ten minutes before the scheduled start of the conference call, or via Internet webcast by logging on to PVR's website at www.pvresource.com at least 20 minutes prior to the scheduled start of the call to download and install any necessary audio software. A telephone replay of the conference call will be available until November 4, 2005, at 11:59 p.m. EST by dialing 1-877-660-6853 and using replay passcodes: account number 286 and conference number 172570. An on-demand replay of the call will also be available at PVR's website beginning shortly after the call.

Penn Virginia Resource Partners, L.P. (NYSE:PVR) is a master limited partnership formed by Penn Virginia Corporation (NYSE:PVA). The Partnership manages coal properties and related assets and operates a midstream natural gas gathering and processing business. PVR is headquartered in Radnor, PA. For more information about PVR, visit the Partnership's website at www.pvresource.com.

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. 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: our ability to generate sufficient cash from our midstream and coal businesses to pay the minimum quarterly distribution; energy prices generally and, specifically, the respective prices of natural gas, NGLs and coal; the relationship between natural gas and NGL prices; the relationship between the price of coal and the prices of natural gas and oil; the volatility of commodity prices for coal, natural gas and NGLs; the projected supply of and demand for coal, natural gas and NGLs; the ability to successfully integrate and manage our new midstream business; the ability to acquire new coal reserves on satisfactory terms; the price for which new coal reserves can be acquired; the ability to lease new and existing coal reserves; the ability to continually find and contract for new sources of natural gas supply; the ability to retain our existing or acquire new midstream customers; the ability of our coal lessees to produce sufficient quantities of coal on an economic basis from our reserves; the ability of our coal lessees to obtain favorable contracts for coal produced from our reserves; competition among producers in the coal industry generally and among midstream companies; the exposure we have to the credit risk of our coal lessees and our midstream customers; the experience and financial condition of our coal lessees, including their ability to satisfy their royalty, environmental, reclamation and other obligations to us and others; the ability to expand our midstream business by constructing new gathering systems, pipelines and processing facilities on an economic basis and in a timely manner; the extent to which the amount and quality of actual coal production differs from estimated recoverable proved coal reserves; unanticipated geological problems; the dependence of our midstream business on having connections to third party pipelines; availability of required materials and equipment; the occurrence of unusual weather or operating conditions, including force majeure events; the failure of our coal infrastructure or our coal lessees' mining equipment or processes to operate in accordance with specifications or expectations; delays in anticipated start-up dates of our coal lessees' mining operations and related coal infrastructure projects; environmental risks affecting the mining of coal reserves and the production, gathering and processing of natural gas; the timing of receipt of necessary governmental permits by our coal 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; uncertainties relating to the outcome of litigation regarding permitting of the disposal of coal overburden; 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); coal handling joint venture operations; and changes in financial market conditions

. Additional information concerning these and other factors can be found in and PVR's press releases and public periodic filings with the Securities and Exchange Commission, including PVR's Annual Report on Form 10-K for the year ended December 31, 2004, filed on March 1, 2005, and subsequently filed interim reports. Many of the factors that will determine PVR's 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. PVR undertakes no obligation to revise or update any forward-looking statements, or to make any other forward-looking statements, whether as a result of new information, future events or otherwise. PENN VIRGINIA RESOURCE PARTNERS, L.P. CONSOLIDATED STATEMENTS OF INCOME - unaudited (in thousands, except per share data) Three Months Ended Nine Months Ended September 30, September 30, ------------------ ------------------ 2005 2004 2005 2004 ---------- ------- --------- -------- Revenues Natural gas midstream $ 103,861 $ - $217,134 $ - Coal royalties 22,739 18,018 60,921 52,395 Coal services 1,261 1,053 3,869 2,779 Other 2,353 326 5,834 918 ---------- ------- --------- -------- 130,214 19,397 287,758 56,092 ---------- ------- --------- -------- Expenses Cost of gas purchased 89,622 - 185,833 - Operating 4,588 1,777 10,730 5,574 Taxes other than income 559 239 1,657 753 General and administrative 3,790 2,077 10,069 6,036 Depreciation, depletion and amortization 9,159 4,764 22,237 14,385 ---------- ------- --------- -------- 107,718 8,857 230,526 26,748 ---------- ------- --------- -------- Operating Income 22,496 10,540 57,232 29,344 Interest expense, net (3,704) (1,393) (9,282) (3,601) Unrealized gain (loss) on derivatives 3,578 - (11,186) - ---------- ------- --------- -------- Net income $ 22,370 $9,147 $ 36,764 $25,743 ---------- ------- --------- -------- Allocation of net income: General partner's interest in net income $ 951 $ 183 $ 1,478 $ 515 Limited partners' interest in net income $ 21,419 $8,964 $ 35,286 $25,228 Basic and diluted net income per limited partner unit, common and subordinated $ 1.03 $ 0.50 $ 1.77 $ 1.40 Weighted average units outstanding: Common 15,085 10,425 14,190 10,419 Subordinated 5,737 7,650 5,737 7,650 ---------------------------------------------------------------------- Other data: Coal royalty tons (in thousands) 8,531 7,971 22,496 23,865 Average gross coal royalty ($ per ton) $ 2.67 $ 2.26 $ 2.71 $ 2.20 Inlet volumes (MMcf) 11,567 - 26,963 - Midstream processing margin ($ per Mcf) $ 1.23 $ - $ 1.16 $ - PENN VIRGINIA RESOURCE PARTNERS, L.P. CONSOLIDATED BALANCE SHEETS (in thousands) September December 30, 31, 2005 2004 ----------- --------- (unaudited) Assets Cash $ 22,217 $ 20,997 Receivables 75,515 8,668 Derivative assets 14,765 - Other current assets 2,670 541 ----------- --------- Total current assets 115,167 30,206 Property and equipment, net 462,782 221,615 Equity investments 26,395 27,881 Goodwill 8,066 - Intangibles, net 37,183 - Derivative assets 9,256 - Other long-term assets 5,659 4,733 ----------- --------- Total assets $ 664,508 $284,435 ----------- --------- Liabilities and Partners' Capital Current portion of long- term debt $ 8,105 $ 4,800 Accounts payable and accrued liabilities 67,083 3,989 Derivative liabilities 27,335 - Other current liabilities 2,314 1,207 ----------- --------- Total current liabilities 104,837 9,996 Other long-term liabilities 35,139 11,529 Long-term debt 249,798 112,926 Partners' capital 274,734 149,984 ----------- --------- Total liabilities and partners' capital $ 664,508 $284,435 ----------- --------- CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited (in thousands) Three Months Ended Nine Months Ended September 30, September 30, --------------------- ------------------ 2005 2004 2005 2004 ----------- --------- --------- -------- Operating Activities Net income $ 22,370 $ 9,147 $ 36,764 $25,743 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 9,159 4,764 22,237 14,385 Unrealized loss (gain) on derivatives, net of settlements (5,462) - 7,461 - Noncash interest expense 177 126 1,519 378 Equity earnings, net of distributions 2,090 (165) 1,546 (165) Changes in operating assets and liabilities 3,579 (1,282) 2,164 (1,618) ----------- --------- --------- -------- Net cash provided by operating activities 31,913 12,590 71,691 38,723 ----------- --------- --------- -------- Investing Activities Acquisitions, net of cash acquired (67,492) (28,442) (290,169) (28,442) Additions to property and equipment (3,795) (72) (9,615) (939) Other - 210 52 585 ----------- --------- --------- -------- Net cash used in investing activities (71,287) (28,304) (299,732) (28,796) ----------- --------- --------- -------- Financing Activities Payments for debt issuance costs (346) - (2,385) - Proceeds from borrowings, net 54,200 27,000 140,200 26,000 Proceeds from issuance of partners' capital 252 - 129,258 - Distributions to partners (14,134) (9,960) (37,812) (29,229) ----------- --------- --------- -------- Net cash provided by (used in) financing activities 39,972 17,040 229,261 (3,229) ----------- --------- --------- -------- Net increase in cash and cash equivalents 598 1,326 1,220 6,698 Cash and cash equivalents- beginning balance 21,619 14,438 20,997 9,066 ----------- --------- --------- -------- Cash and cash equivalents- ending balance $ 22,217 $ 15,764 $ 22,217 $15,764 ----------- --------- --------- -------- Noncash Investing and Financing Activities Issuance of partners' capital for acquisition $ 10,415 $ - $ 10,415 $ 1,060 Assumption of liabilities in acquisition $ 3,981 $ - $ 3,981 $ - PENN VIRGINIA RESOURCE PARTNERS, L.P. QUARTER SEGMENT INFORMATION - unaudited (Dollars in thousands except where noted) Natural Gas Midstream (1) ------------------------- Coal Amount (per Mcf) Consolidated -------- ------------- ----------- ------------ Three months ended September 30, 2005 Revenues Natural gas midstream $ - $ 103,861 $ 103,861 Coal royalties 22,739 - 22,739 Coal services 1,261 - 1,261 Other 1,923 430 2,353 -------- ------------- ------------ Total revenues 25,923 104,291 $ 9.02 130,214 -------- ------------- ------------ Expenses Cost of gas purchased - 89,622 7.75 89,622 Operating 1,931 2,657 0.23 4,588 Taxes other than income 219 340 0.03 559 General and administrative 1,917 1,873 0.16 3,790 Depreciation, depletion and amortization 5,257 3,902 0.34 9,159 -------- ------------- ----------- ------------ Total expenses 9,324 98,394 8.51 107,718 -------- ------------- ----------- ------------ Operating Income $16,599 $ 5,897 $ 0.51 $ 22,496 -------- ------------- ----------- ------------ Production Coal royalty tons (thousands of tons) 8,531 Inlet volumes (MMcf) 11,567 Additions to property and equipment and acquisitions, net of cash acquired (2) $81,339 $ 4,344 $ 85,683 ---------------------------------------------------------------------- Natural Gas Midstream (1) ------------------------- Coal Amount (per Mcf) Consolidated -------- ------------- ----------- ------------ Three months ended September 30, 2004 Revenues Natural gas midstream $ - $ - $ - Coal royalties 18,018 - 18,018 Coal services 1,053 - 1,053 Other 326 - 326 -------- ------------- ------------ Total revenues 19,397 - $ - 19,397 -------- ------------- ------------ Expenses Cost of gas purchased - - - - Operating 1,777 - - 1,777 Taxes other than income 239 - - 239 General and administrative 2,077 - - 2,077 Depreciation, depletion and amortization 4,764 - - 4,764 -------- ------------- ----------- ------------ Total expenses 8,857 - - 8,857 -------- ------------- ----------- ------------ Operating Income $10,540 $ - $ - $ 10,540 -------- ------------- ----------- ------------ Production Coal royalty tons (thousands of tons) 7,971 Additions to property and equipment and acquisitions, net of cash acquired $ 72 $ - $ 72 (1) Natural Gas Midstream segment acquired in March 2005. (2) Coal segment includes noncash expenditures of $14.4 million. PENN VIRGINIA RESOURCE PARTNERS, L.P. YEAR-TO-DATE SEGMENT INFORMATION - unaudited (Dollars in thousands except where noted) Natural Gas Midstream (1) ------------------------- Coal Amount (per Mcf) Consolidated --------- ------------- ----------- ------------ Nine months ended September 30, 2005 Revenues Natural gas midstream $ - $ 217,134 $ 217,134 Coal royalties 60,921 - 60,921 Coal services 3,869 - 3,869 Other 4,638 1,196 5,834 --------- ------------- ------------ Total revenues 69,428 218,330 $ 8.10 287,758 --------- ------------- ------------ Expenses Cost of gas purchased - 185,833 6.89 185,833 Operating 4,104 6,626 0.25 10,730 Taxes other than income 727 930 0.03 1,657 General and administrative 5,962 4,107 0.15 10,069 Depreciation, depletion and amortization 13,440 8,797 0.33 22,237 --------- ------------- ----------- ------------ Total expenses 24,233 206,293 7.65 230,526 --------- ------------- ----------- ------------ Operating Income $ 45,195 $ 12,037 $ 0.45 $ 57,232 --------- ------------- ----------- ------------ Production Coal royalty tons (thousands of tons) 22,496 Inlet volumes (MMcf) 26,963 Additions to property and equipment and acquisitions, net of cash acquired (2) $110,370 $ 203,810 $ 314,180 ---------------------------------------------------------------------- Natural Gas Midstream (1) ------------------------- Coal Amount (per Mcf) Consolidated --------- ------------- ----------- ------------ Nine months ended September 30, 2004 Revenues Natural gas midstream $ - $ - $ - Coal royalties 52,395 - 52,395 Coal services 2,779 - 2,779 Other 918 - 918 --------- ------------- ------------ Total revenues 56,092 - $ - 56,092 --------- ------------- ------------ Expenses Cost of gas purchased - - - - Operating 5,574 - - 5,574 Taxes other than income 753 - - 753 General and administrative 6,036 - - 6,036 Depreciation, depletion and amortization 14,385 - - 14,385 --------- ------------- ----------- ------------ Total expenses 26,748 - - 26,748 --------- ------------- ----------- ------------ Operating Income $ 29,344 $ - $ - $ 29,344 --------- ------------- ----------- ------------ Production Coal royalty tons (thousands of tons) 23,865 Additions to property and equipment and acquisitions, net of cash acquired (3) $ 1,999 $ - $ 1,999 (1) Natural Gas Midstream segment acquired in March 2005. (2) Coal segment includes noncash expenditures of $14.4 million. (3) Coal segment includes noncash expenditures of $1.1 million. PENN VIRGINIA RESOURCE PARTNERS, L.P. RECONCILIATION OF CERTAIN NON-GAAP FINANCIAL MEASURES - unaudited (in thousands) Three Months Ended Nine Months Ended September 30, September 30, ------------------ ------------------ 2005 2004 2005 2004 --------- -------- --------- -------- Reconciliation of GAAP "Net income (loss)" to Non-GAAP "EBITDA" -------------------------------- Net income $ 22,370 $ 9,147 $ 36,764 $25,743 Interest expense, net 3,704 1,393 9,282 3,601 Depreciation, depletion and amortization 9,159 4,764 22,237 14,385 --------- -------- --------- -------- EBITDA (see Note 1 below) $ 35,233 $15,304 $ 68,283 $43,729 --------- -------- --------- -------- Reconciliation of GAAP "Net income (loss)" to Non-GAAP "Distributable cash flow" -------------------------------- Net income $ 22,370 $ 9,147 $ 36,764 $25,743 Depreciation, depletion and amortization 9,159 4,764 22,237 14,385 Unrealized loss (gain) on derivatives, net of settlements (5,462) - 7,461 - Other property and equipment expenditures (2,280) (72) (4,000) (939) --------- -------- --------- -------- Distributable cash flow (see Note 2 below) $ 23,787 $13,839 $ 62,462 $39,189 --------- -------- --------- -------- Reconciliation of GAAP "Additions to property and equipment" to Non-GAAP "Capital expenditures" -------------------------------- Additions to property and equipment $ 3,795 $ 72 $ 9,615 $ 939 Acquisitions, net of cash acquired 67,492 28,442 290,169 28,442 Noncash lease acquisitions 14,396 - 14,396 1,060 --------- -------- --------- -------- Capital expenditures (see Note 3 below) $ 85,683 $28,514 $314,180 $30,441 --------- -------- --------- -------- Note 1 - EBITDA represents net income before income tax expense, interest expense, and depreciation, depletion and amortization expense. Management believes EBITDA provides additional, useful information regarding PVR's ability to meet our debt service, capital expenditure and working capital requirements. EBITDA is a traditional measure of a business' ability to generate cash flows irrespective of financing costs and is presented as a supplemental financial measurement in the evaluation of our business. This measure is widely used by investors and rating agencies in the valuation, comparison, rating and investment recommendations of companies. EBITDA is the most widely-used financial measure by commercial banks, investment bankers, fixed-income investors and ratings agencies. It is also a financial measurement that, with certain negotiated adjustments, is reported to our banks under our bank credit facility and is used in our financial covenants under our bank credit facility and the indenture governing our senior unsecured notes. EBITDA is not a measure of financial performance under GAAP. Accordingly, it should not be considered as a substitute for net income, income from operations or net cash flows provided by operating activities prepared in accordance with GAAP. Note 2 - Distributable cash flow represents income before income tax expense, depreciation, depletion and amortization expense and unrealized loss on derivatives (net of cash paid or received on those derivatives during the period), minus other capital expenditures. Other property and equipment expenditures are capital expenditures (as defined by GAAP) which do not increase the capacity of an asset or generate additional revenues or net cash from operating activities. Distributable cash flow is presented because management believes it is a useful adjunct to net cash provided by operating activities under accounting principles generally accepted in the United States (GAAP). Distributable cash flow is a significant liquidity metric which is an indicator of PVR's ability to generate cash flows at a level that can sustain or support an increase in quarterly cash distributions paid to its partners. Distributable cash flow is also the quantitative standard used throughout the investment community with respect to publicly-traded partnerships. Distributable cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing or financing activities, as an indicator of cash flows or as a measure of liquidity. Note 3 - Capital expenditures represents cash additions to property and equipment, plus cash paid for acquisitions and other expenditures. Management believes capital expenditures provide useful information regarding the Company's capital program as a supplement to cash additions to property and equipment. Penn Virginia Resource Partners, L.P. Guidance Table (Dollars and tons in millions) Penn Virginia Resource Partners, L.P. is providing the following guidance regarding financial and operational expectations for the fourth quarter and full year 2005. Actual ------------------------------------------------- First Quarter Second Quarter Third Quarter YTD 2005 2005 2005 2005 ------------- -------------- ------------- ------ Coal Segment: -------------------- Coal royalty tons (millions) 6.7 7.3 8.5 22.5 Revenues: Average coal royalty per ton $ 2.69 2.78 2.67 2.71 Other $ 1.7 3.6 3.2 8.5 Expenses: Direct expenses $ 3.6 3.1 4.1 10.8 Depreciation, depletion and amortization $ 3.9 4.3 5.3 13.4 Capital Expenditures: Coal segment acquisitions $ 9.3 15.4 80.8 105.5 Coal segment other expenditures $ - 4.3 0.6 4.9 Total Coal Capital Expenditures $ 9.3 19.7 81.4 110.4 Natural Gas Midstream Segment: (a) -------------------- Inlet volumes (MMcf per day) - (b) 126 126 126 126 Expenses: Direct expenses $ 1.3 5.5 4.9 11.7 Depreciation, depletion and amortization $ 1.2 3.7 3.9 8.8 Capital Expenditures: Midstream segment acquisitions, net of cash $ 195.7 2.3 1.1 199.1 Midstream segment other expenditures $ 0.3 1.3 3.1 4.7 Total Midstream Capital Expenditures $ 196.0 3.6 4.2 203.8 Other: -------------------- Interest expense: Average long- term debt outstanding $ 134.8 205.3 248.2 195.2 Net interest rate 5.0% 5.5% 5.8% 5.8% Guidance --------------------------------------- Fourth Quarter Full Year 2005 2005 -------------------- ------------------ Coal Segment: ------------------------------ Coal royalty tons (millions) 7.2 - 7.9 29.7 - 30.4 Revenues: Average coal royalty per ton $ 2.50 - 2.60 2.65 - 2.70 Other $ 3.7 - 4.0 12.2 - 12.5 Expenses: Direct expenses $ 3.0 - 3.3 13.8 - 14.1 Depreciation, depletion and amortization $ 4.4 - 4.8 17.8 - 18.2 Capital Expenditures: Coal segment acquisitions $ - - - 105.5 - 105.5 Coal segment other expenditures $ 4.7 - 5.7 9.6 - 10.6 Total Coal Capital Expenditures $ 4.7 - 5.7 115.1 - 116.1 Natural Gas Midstream Segment: (a) ------------------------------ Inlet volumes (MMcf per day) - (b) 120 - 130 124 - 127 Expenses: Direct expenses $ 4.5 - 5.0 16.2 - 16.7 Depreciation, depletion and amortization $ 3.5 - 3.9 12.3 - 12.7 Capital Expenditures: Midstream segment acquisitions, net of cash $ - - - 199.1 - 199.1 Midstream segment other expenditures $ 1.6 - 2.3 6.3 - 7.0 Total Midstream Capital Expenditures $ 1.6 - 2.3 205.4 - 206.1 Other: ------------------------------ Interest expense: Average long-term debt outstanding $ 252.8 - 263.2 202.8 - 211.1 Net interest rate 6.5% 6.5% These estimates are meant to provide guidance only and are subject to revision as the operating environment of Penn Virginia Resource Partners, L.P. changes. Notes: (a) Actual results and full year guidance include the natural gas midstream segment from the date of the Cantera Acquisition in March 2005. (b) The natural gas midstream segment's natural gas liquids, natural gas and oil hedging positions as of 9/30/05 are summarized below: Average Weighted Volume Average Per Day Price --------- ------------ Ethane Swaps (gallons) (per gallon) ------------ Fourth Quarter 2005 - Fourth Quarter 2006 68,800 $ 0.4770 First Quarter 2007 - Fourth Quarter 2007 34,440 $ 0.5050 First Quarter 2008 - Fourth Quarter 2008 34,440 $ 0.4700 Propane Swaps (gallons) (per gallon) ------------- Fourth Quarter 2005 - Fourth Quarter 2006 52,080 $ 0.7060 First Quarter 2007 - Fourth Quarter 2007 26,040 $ 0.7550 First Quarter 2008 - Fourth Quarter 2008 26,040 $ 0.7175 Crude Oil Swaps (Bbls) (per Bbl) --------------- Fourth Quarter 2005 - Fourth Quarter 2006 1,100 $ 44.45 First Quarter 2007 - Fourth Quarter 2007 560 $ 50.80 First Quarter 2008 - Fourth Quarter 2008 560 $ 49.27 Natural Gas Swaps (Mmbtu) (per Mmbtu) ----------------- Fourth Quarter 2005 - Fourth Quarter 2006 7,500 $ 7.05 First Quarter 2007 - Fourth Quarter 2008 4,000 $ 6.97

Source: Business Wire

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