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PVR Partners Announces Third Quarter Results and Increases Quarterly Distribution

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RADNOR, Pa., Oct. 24, 2012 /PRNewswire/ -- PVR Partners, L.P. (NYSE: PVR) ("PVR") today reported financial and operational results for the three months ended September 30, 2012.  In addition, PVR announced an increase in its quarterly distribution to $0.54 per unit.

(Logo: http://photos.prnewswire.com/prnh/20110224/PH54022LOGO )

Third Quarter Results

Third quarter 2012 highlights and results, with comparisons to third quarter 2011 results, included the following:

  • Adjusted EBITDA of $61.2 million as compared to $60.0 million.
  • Distributable cash flow ("DCF") of $29.9 million as compared to $36.1 million.
  • Adjusted net income of $7.7 million as compared to $20.5 million.

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

Quarterly Distribution

The Board of Directors of PVR GP, LLC, the general partner of PVR, declared a quarterly distribution of $0.54 per unit payable in cash on November 14, 2012 to common unitholders of record at the close of business on November 7, 2012.  This distribution equates to an annualized rate of $2.16 per unit, and represents a 1.9% increase over the prior quarter distribution and an 8.0% increase over the third quarter of 2011.

Management Comment

"While our operating results continue to be impacted by very challenging coal markets and low NGL prices in the Midcontinent Midstream Segment, the solid growth of our Eastern Midstream business continued during the third quarter," said Bill Shea, President and CEO of PVR's general partner.  "The strong volume gains and operating results of our Eastern Midstream Segment reflect the growing positive impacts of the acquisition of Chief Gathering and the continuing build out of our Lycoming system and other internal growth projects in the Marcellus.  With the recent start of operation of our new Wyoming County Pipeline, we expect continued strong growth in the Eastern Midstream Segment during the fourth quarter."

Eastern Midstream Segment

The Eastern Midstream Segment reported third quarter 2012 results, with comparisons to third quarter 2011 results, as follows:

  • Adjusted EBITDA of $21.4 million as compared to $6.6 million, primarily due to the continued development of internal growth projects and the acquisition of Chief Gathering LLC.
  • Quarterly average throughput volumes of 456 million cubic feet per day ("MMcfd"), as compared to 63 MMcfd.  The volume growth reflects the expansion of business on PVR's existing Lycoming and Wyoming systems, as well as the acquisition of Chief Gathering.

Midcontinent Midstream Segment

The Midcontinent Midstream Segment reported third quarter 2012 results, with comparisons to third quarter 2011 results, as follows:

  • Adjusted EBITDA of $13.0 million as compared to $14.1 million, primarily due to low NGL prices, the migration to lower-margin fee-based contracts, and the sale of our Crossroads system.
  • Quarterly average throughput volumes of 410 MMcfd, as compared to 441 MMcfd.  Third quarter 2011 volumes include approximately 48 MMcfd attributable to the Crossroads system that was sold on July 3, 2012.

Coal and Natural Resource Management Segment

The Coal and Natural Resource Management Segment reported third quarter 2012 results, with comparisons to third quarter 2011 results, as follows:

  • Adjusted EBITDA of $26.8 million as compared to $39.4 million, primarily due to decreased coal production and pricing.
  • Coal royalty tons of 7.7 million tons, as compared to 9.5 million tons.
  • Coal royalties revenue of $28.8 million, or $3.73 per ton, as compared to $41.0 million, or $4.32 per ton.

Capital Investment and Resources

We invested approximately $150.0 million on internal growth projects during the third quarter of 2012, including $130.6 million in the Eastern Midstream Segment.  We now expect 2012 internal growth capital to total approximately $485 million.

As of September 30, 2012, we had borrowings of $535.0 million under our $1.0 billion revolving credit facility with remaining borrowing capacity thereunder of $457.1 million.

Expansion Projects Update

As previously reported, the Wyoming County Pipeline began full commercial operation at the end of the third quarter.  Current volumes on the Wyoming County Pipeline are approximately 325 MMcfd.  Construction continues to progress on Phase III and the Canton Lateral on our Lycoming County, Pennsylvania gas trunkline and water line, and these projects are expected to be in service by the end of the fourth quarter to gather gas for an affiliate of Southwestern Energy Company and a subsidiary of Royal Dutch Shell.  Construction of the first phase of the new gathering system in Lycoming County to service the acreage dedications of Inflection Energy has also begun and is proceeding on schedule.

Financial Guidance for 2012

PVR's financial guidance for full year 2012 Adjusted EBITDA in the range of $245 - $260 million and full year 2012 distributable cash flow, net of maintenance and replacement capital, in the range of $120 - $130 million is unchanged from guidance provided with the second quarter results in July.  PVR's financial guidance is based on numerous assumptions about future events and conditions and, therefore, could vary materially from actual results.  These estimates, including capital expenditure plans, are meant to provide guidance only and are subject to revision for acquisitions or operating environment changes.  Adjusted EBITDA and distributable cash flow are non-GAAP measures; reconciliations of these non-GAAP measures to GAAP reporting measures appear in the financial tables which follow.

Third Quarter 2012 Financial and Operational Results Conference Call

A conference call and webcast, during which management will discuss third quarter 2012 financial and operational results, is scheduled for Wednesday, October 24, 2012 at 11:00 a.m. EDT.  Prepared remarks by William H. Shea, Jr., President and Chief Executive Officer, and other members of company management will be followed by a question and answer period.  Interested parties may listen via webcast at http://www.videonewswire.com/event.asp?id=89879 or by logging on using the link posted on our website, www.pvrpartners.com.  Participants who would like to ask questions may join the conference via phone by dialing 800-860-2442 (international 412-858-4600) five to ten minutes before the scheduled start of the conference call (reference the PVR Partners call).  An on-demand replay of the webcast will be available on our website shortly after the conclusion of the call.  A telephonic replay of the call will be available through October 30 by dialing 877-344-7529 (international: 412-317-0088) and using conference playback number 10019447.

******

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

******

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

******

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

 

PVR PARTNERS, L.P.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - unaudited

(in thousands, except per unit data)






























Three Months Ended


Nine Months Ended



September 30,


September 30,



2012


2011


2012


2011

Revenues







     Natural gas 


$          78,026


$          120,240


$         215,780


$     324,447

     Natural gas liquids


96,237


129,389


316,161


374,279

     Gathering and transportation


27,229


10,081


62,488


24,172

     Coal royalties


28,760


40,977


91,150


124,546

     Gain on sale of plant


31,292


-


31,292


-

     Other


7,303


7,665


21,305


24,757

Total revenues


268,847


308,352


738,176


872,201










Expenses









     Cost of gas purchased


147,246


223,762


453,543


613,295

     Operating


17,587


15,797


47,530


43,112

     General and administrative


11,531


8,755


34,574


31,700

     Acquisition related costs


-


-


14,049


-

     Impairments


-


-


124,845


-

     Depreciation, depletion and amortization


31,992


22,463


84,301


65,357

Total expenses


208,356


270,777


758,842


753,464










Operating income (loss)


60,491


37,575


(20,666)


118,737










Other income (expense)









     Interest expense


(20,288)


(10,528)


(45,616)


(33,806)

     Derivatives


(1,524)


8,690


2,201


(6,289)

     Interest income and other


104


120


329


384

Net income (loss) 


38,783


35,857


(63,752)


79,026

Net loss (income) attributable to noncontrolling interests (pre-merger)


-


-


-


664

Net income (loss) attributable to PVR Partners', L.P.


$          38,783


$            35,857


$          (63,752)


$       79,690



















Earnings per common unit, basic and diluted


$              0.16


$                0.50


$              (1.14)


$           1.26










Weighted average number of common units outstanding, basic and diluted


88,366


71,197


83,834


63,019










Weighted average number of Class B units outstanding


21,620




10,770



Weighted average number of Special units outstanding


10,346




5,173





















Other data:


















Daily throughput volumes (MMcfd) - Eastern Midstream


456


63


337


47

Daily throughput volumes (MMcfd) - Midcontinent Midstream


410


441


435


415

Coal royalty tons (in thousands)


7,703


9,479


23,584


29,501










 

 

 

PVR PARTNERS, L.P.


CONDENSED CONSOLIDATED BALANCE SHEETS - unaudited


(in thousands)














September 30,


December 31,








2012


2011
















Assets










     Cash and cash equivalents


$          10,127


$              8,640






     Accounts receivable


97,443


101,340






     Other current assets


5,314


5,640






         Total current assets


112,884


115,620






     Property, plant and equipment, net


1,822,010


1,282,297






     Other long-term assets


854,140


196,075






          Total assets


$     2,789,034


$       1,593,992
















Liabilities and Partners' Capital










     Accounts payable and accrued liabilities


$        152,754


$          124,082






     Deferred income


3,963


3,416






     Derivative liabilities


1,787


12,042






         Total current liabilities


158,504


139,540






     Other long-term liabilities


33,933


31,748






     Senior notes 


900,000


300,000






     Revolving credit facility


535,000


541,000






     Partners' capital


1,161,597


581,704






          Total liabilities and partners' capital


$     2,789,034


$       1,593,992


























CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited


(in thousands)














Three Months Ended


Nine Months Ended




September 30,


September 30,




2012


2011


2012


2011


Cash flows from operating activities






     Net income (loss)


$          38,783


$            35,857


$          (63,752)


$       79,026


     Adjustments to reconcile net income to










          net cash provided by operating activities:










     Gain on sale of plant


(31,292)


-


(31,292)


-


     Depreciation, depletion and amortization


31,992


22,463


84,301


65,357


     Impairments


-


-


124,845


-


     Commodity derivative contracts:










     Total derivative losses included in net income


1,524


(8,690)


(2,201)


6,289


     Cash payments to settle derivatives for the period


(1,332)


(6,699)


(8,578)


(19,477)


     Non-cash interest expense


1,589


1,040


4,217


4,735


     Non-cash unit-based compensation


1,086


966


4,643


2,805


     Equity earnings, net of distributions received


697


2,818


142


4,635


     Other


(231)


(127)


(929)


(909)


     Changes in operating assets and liabilities


23,334


2,329


23,396


(153)


Net cash provided by operating activities


66,150


49,957


134,792


142,308












Cash flows from investing activities










Acquisitions, net of cash acquired


787


(95)


(850,156)


(122,135)


Additions to property, plant and equipment


(173,455)


(67,000)


(348,449)


(141,796)


Proceeds for sale of plant


62,271


-


62,271


-


Other


(9,932)


347


(20,992)


2,558


Net cash used in investing activities


(120,329)


(66,748)


(1,157,326)


(261,373)












Cash flows from financing activities










Net proceeds from equity offerings


(219)


-


577,743


-


Proceeds from issuance of senior notes


-


-


600,000


-


Distributions to partners


(46,833)


(34,887)


(128,516)


(99,696)


Proceeds from (repayments of) borrowings, net


103,000


55,000


(6,000)


227,000


Cash paid for debt issuance costs


(617)


-


(19,206)


(3,675)


Cash paid for merger


-


(16)


-


(6,620)


Net cash provided by financing activities


55,331


20,097


1,024,021


117,009












Net increase (decrease) in cash and cash equivalents


1,152


3,306


1,487


(2,056)


Cash and cash equivalents - beginning of period


8,975


10,602


8,640


15,964


Cash and cash equivalents - end of period


$          10,127


$            13,908


$           10,127


$       13,908


 

 

 

 

PVR PARTNERS, L.P.

CERTAIN NON-GAAP FINANCIAL MEASURES - unaudited

(in thousands)
















Three Months Ended


Nine Months Ended







September 30,


September 30,


Guidance Range



2012


2011


2012


2011


Full Year 2012

Reconciliation of Non-GAAP "Segment Adjusted EBITDA" to GAAP "Net income (loss)":

























Segment Adjusted EBITDA (a):













Eastern Midstream


$      21,440


$        6,583


$      49,060


$      14,547


$    87,000


$    93,000

Midcontinent Midstream


12,994


14,052


38,001


51,084


58,000


62,000

Coal and Natural Resource Management


26,757


39,403


84,176


118,463


100,000


105,000

Total segment adjusted EBITDA


$      61,191


$      60,038


$    171,237


$    184,094


$  245,000


$  260,000

Adjustments to reconcile total Segment Adjusted EBITDA to Net income (loss)













Depreciation, depletion and amortization


(31,992)


(22,463)


(84,301)


(65,357)





Impairments


-


-


(124,845)


-





Acquisition related costs


-


-


(14,049)


-





Gain on sale of plant


31,292


-


31,292


-





Interest expense


(20,288)


(10,528)


(45,616)


(33,806)





Derivatives


(1,524)


8,690


2,201


(6,289)





Other


104


120


329


384





Net income (loss)


$      38,783


$      35,857


$    (63,752)


$      79,026


















Reconciliation of GAAP "Net income (loss)" to Non-GAAP "Distributable cash flow":













Net income (loss)


$      38,783


$      35,857


$    (63,752)


$      79,026


$  (45,000)


$  (42,000)

Depreciation, depletion and amortization


31,992


22,463


84,301


65,357


115,000


118,000

Impairment


-


-


124,845


-


125,000


125,000

Acquisition related costs


-


-


14,049


-


14,000


14,000

Gain on sale of plant


(31,292)


-


(31,292)


-


(31,300)


(31,300)

Derivative contracts:













  Derivative losses included in net income


1,524


(8,690)


(2,201)


6,289


(2,000)


(1,000)

  Cash payments to settle derivatives for the period


(1,332)


(6,699)


(8,578)


(19,477)


(11,000)


(10,000)

Equity earnings from joint ventures, net of distributions


697


2,818


142


4,635


(500)


500

Maintenance capital expenditures


(3,749)


(2,884)


(12,197)


(8,532)


(17,200)


(16,200)

Replacement capital expenditures


(6,725)


(6,725)


(20,175)


(20,175)


(27,000)


(27,000)














Distributable cash flow (b)


$      29,898


$      36,140


$      85,142


$    107,123


$  120,000


$  130,000














Distribution to Partners:


























Total cash distribution paid during the period


$      46,833


$      34,887


$    128,516


$      99,696


















Reconciliation of GAAP "Net income (loss)" to Non-GAAP "Net income as adjusted":













Net income (loss)


$      38,783


$      35,857


$    (63,752)


$      79,026





Impairments


-


-


124,845


-





Acquisition related costs


-


-


14,049


-





Gain on sale of plant


(31,292)


-


(31,292)


-





Adjustments for derivatives:













Derivative losses included in net income


1,524


(8,690)


(2,201)


6,289





Cash payments to settle derivatives for the period


(1,332)


(6,699)


(8,578)


(19,477)


















Net income, as adjusted (c)


$        7,683


$      20,468


$      33,071


$      65,838


















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


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


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

 

 

PVR PARTNERS, L.P.

QUARTERLY SEGMENT INFORMATION - unaudited

(in thousands)












Eastern Midstream



Three Months Ended


Nine Months Ended



September 30,


September 30,



2012


2011


2012


2011

Revenues









     Gathering and transportation


$          25,759


$            7,720


$         56,710


$         16,582

     Other


1,041


-


2,687


-

        Total revenues


26,800


7,720


59,397


16,582

Expenses









     Operating 


2,124


635


4,211


898

     General and administrative


3,236


502


6,126


1,137

     Acquisition related costs


-


-


14,049


-

     Depreciation, depletion and amortization


11,867


987


22,322


2,151

       Total expenses


17,227


2,124


46,708


4,186










Operating income


$            9,573


$            5,596


$         12,689


$         12,396





















Midcontinent Midstream



Three Months Ended


Nine Months Ended



September 30,


September 30,



2012


2011


2012


2011

Revenues









     Natural gas


$          78,026


$        120,240


$       215,780


$       324,447

     Natural gas liquids


96,237


129,389


316,161


374,279

     Gathering and transportation


1,470


2,361


5,778


7,590

     Gain on sale of plant


31,292


-


31,292


-

     Other


497


1,186


2,042


4,874

        Total revenues


207,522


253,176


571,053


711,190

Expenses









     Cost of gas purchased


147,246


223,762


453,543


613,295

     Operating 


11,164


10,880


31,642


30,399

     General and administrative


4,826


4,482


16,575


16,412

     Impairments


-


-


124,845


-

     Depreciation, depletion and amortization


11,913


11,904


37,220


35,228

       Total expenses


175,149


251,028


663,825


695,334










Operating income (loss) 


$          32,373


$            2,148


$        (92,772)


$         15,856






























Coal and Natural Resource Management



Three Months Ended


Nine Months Ended



September 30,


September 30,



2012


2011


2012


2011

Revenues









     Coal royalties


$          28,760


$          40,977


$         91,150


$       124,546

     Coal services


1,953


2,151


4,583


6,739

     Timber


1,411


1,457


4,284


3,834

     Oil and gas royalties


977


1,234


2,165


3,016

     Other


1,424


1,637


5,544


6,294

        Total revenues


34,525


47,456


107,726


144,429

Expenses









     Operating 


4,299


4,282


11,677


11,815

     General and administrative


3,469


3,771


11,873


14,151

     Depreciation, depletion and amortization


8,212


9,572


24,759


27,978

       Total expenses


15,980


17,625


48,309


53,944










Operating income


$          18,545


$          29,831


$         59,417


$         90,485



















 

 

 

PVR PARTNERS, L.P.

DERIVATIVE CONTRACT SUMMARY - unaudited

As of September 30, 2012












Average

Volume Per

Day














Swap


Weighted Average Price




Price


Put (a)


Call (b)










NGL - natural gasoline collar


 (gallons) 




(per gallon)

Fourth quarter 2012


54,000




$1.75


$2.02










Crude swap


 (barrels) 


(per barrel)





Fourth quarter 2012


600


$88.62














Natural gas purchase swap


 (MMBtu) 


(MMBtu)





Fourth quarter 2012


4,000


$5.195














We estimate that, excluding the effects of derivative positions described above, for every $1.00 per MMBtu increase or decrease in the natural gas price, our natural gas midstream gross margin and operating income (loss) for the remainder of 2012 would increase or decrease by $0.1 million. In addition, we estimate that for every $5.00 per barrel increase or decrease in the crude oil price, our natural gas midstream gross margin and operating income (loss) for the remainder of 2012 would increase or decrease by $2.0 million. This assumes that natural gas prices, crude oil prices and inlet volumes remain constant at anticipated levels. These estimated changes in our gross margin and operating income (loss) exclude potential cash receipts or payments in settling these derivative positions.


(a) - Purchased put/floor.

(b) - Sold call/ceiling.

 

 

Contact:

Stephen R. Milbourne


Director - Investor Relations


Phone: 610-975-8204


E-Mail: invest@pvrpartners.com

 

SOURCE PVR Partners, L.P.



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