PVR Partners Announces First Quarter 2013 Results and Declares Cash Distribution

RADNOR, Pa., April 25, 2013 /PRNewswire/ -- PVR Partners, L.P. (NYSE: PVR) ("PVR") today reported financial and operational results for the three months ended March 31, 2013.  In addition, PVR declared a quarterly distribution of $0.55 per unit.

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First Quarter Results

First quarter 2013 highlights and results, with comparisons to first quarter 2012 results ("last year") and the fourth quarter of 2012 ("last quarter"), included the following:

  • Adjusted EBITDA of $76.0 million as compared to $53.0 million last year and $67.8 million last quarter.
  • Distributable Cash Flow ("DCF") of $49.9 million as compared to $35.8 million last year and $40.7 million last quarter.
  • Average daily natural gas throughput volumes of 1,619 million cubic feet per day ("MMcfd") as compared with 744 MMcfd last year and 1,388 MMcfd last quarter.

Adjusted EBITDA and DCF 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 $0.55 per unit payable in cash on May 14, 2013 to common unitholders of record at the close of business on May 8, 2013.  This distribution equates to an annualized rate of $2.20 per unit, which is unchanged from the distribution paid with respect to the fourth quarter of 2012 and represents 5.8% increase over the distribution paid with respect to the first quarter of 2012.

Management Comment

"We were pleased with our overall results for the first quarter, particularly with the continuing growth of our Eastern midstream business.  Our Eastern Midstream Segment results reflected the impact of our acquisition of Chief Gathering and the continuing build-out of our growth projects in the Marcellus," said Bill Shea, President and CEO of PVR's general partner.

"Our average Eastern trunkline volumes increased by approximately 60% from the fourth quarter of 2012, and by 600% compared to the first quarter a year ago.  Eastern midstream gathering volumes this quarter were up by about 4% compared to last quarter and rose by more than 175% compared to the first quarter last year.  Adjusted EBITDA for the Eastern Segment increased by approximately 14% over last quarter and was up by more than 275% compared to the first quarter of 2012.

"The Midcontinent Midstream Segment Adjusted EBITDA improved by 27% as compared to last year before making any adjustment for the sale of our Crossroads System," continued Mr. Shea.  "The improved results reflected the additional throughput capacity from our investments in the expansion of the Antelope Hills plant.

"The coal business performed in-line with our expectations, with first quarter production approximately equal to production during the fourth quarter of last year.  The lower average royalty rate for this year's first quarter versus the first quarter of 2012 primarily reflected the proportionally larger decline in higher-royalty rate Central Appalachian production," concluded Mr. Shea.

Eastern Midstream Segment

The Eastern Midstream Segment reported first quarter 2013 results, with comparisons to first quarter 2012 results ("last year") and the fourth quarter of 2012 ("last quarter"), as follows:

  • Adjusted EBITDA of $37.7 million as compared to $10.0 million last year and $33.1 million last quarter, primarily due to the continued development of internal growth projects and the acquisition of Chief Gathering LLC.
  • Quarterly average throughput volumes of 1,228 MMcfd as compared to 302 MMcfd last year and 967 MMcfd last quarter.  The volume growth reflects the expansion of business on PVR's existing systems, as well as the acquisition and expansion of the Chief Gathering systems.

Midcontinent Midstream Segment

The Midcontinent Midstream Segment reported first quarter 2013 results, with comparisons to first quarter 2012 results ("last year") and the fourth quarter of 2012 ("last quarter"), as follows:

  • Adjusted EBITDA of $15.7 million as compared to $12.3 million last year and $14.2 million last quarter.
  • Quarterly average throughput volumes of 391 MMcfd as compared to 442 MMcfd last year and 421 MMcfd last quarter.  First quarter 2012 volumes include approximately 57 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 first quarter 2013 results, with comparisons to first quarter 2012 results ("last year") and the fourth quarter of 2012 ("last quarter"), as follows:

  • Adjusted EBITDA of $22.7 million as compared to $30.7 million last year and $20.5 million last quarter.  The year-over-year decline was primarily due to decreased coal production and pricing.
  • Coal royalty tons of 6.4 million tons as compared to 8.1 million tons last year and 6.6 million tons last quarter.
  • Coal royalties revenue of $23.0 million, or $3.56 per ton, as compared to $33.2 million, or $4.09 per ton last year and $23.0 million or $3.47 per ton last quarter.

Capital Investment and Resources

We invested $90.1 million on internal growth projects in our midstream businesses during the first quarter of 2013, of which $72.7 million was invested in the Eastern Midstream Segment.

As of March 31, 2013, we had borrowings of $700.0 million under our $1.0 billion revolving credit facility, with remaining borrowing capacity thereunder of $292.1 million after adjusting for outstanding letters of credit.

Expansion Projects Update

The development and build-out of important growth projects in the Marcellus, Utica, Cline and Mississippian Lime continued during the first quarter of 2013.

  • Construction of a major new compressor facility and central delivery point on the Wyoming County Trunkline is expected to be completed and begin operation late in the second quarter of this year.
  • We completed 30 new well connections in the Eastern Midstream Segment during the first quarter.
  • We completed 53 new well connections in the Midcontinent Midstream Segment during the first quarter.
  • We continue to build additional phases of the East Lycoming gathering system for which Inflection Energy is the primary shipper.
  • Our project to extend our original Wyoming County Gathering System also continued during the first quarter.
  • We executed an agreement with a major producer in the Utica Shale to share early stage development costs for a gathering and trunkline system similar to our systems in the Marcellus Shale.
  • Work on construction of our gathering system in Greene County, Pennsylvania also continued to progress during the quarter.
  • We executed an agreement with a major producer in the Cline Shale formation for gathering and processing services at our Hamlin plant.
  • We continue to add new wells in our Crescent System as the Mississippian Lime formation develops.

First Quarter 2013 Financial and Operational Results Conference Call

A conference call and webcast, during which management will discuss first quarter 2013 financial and operational results, is scheduled for Thursday, April 25, 2013 at 11:00 a.m. Eastern Daylight Time.  Prepared remarks by 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=93357 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 May 1 by dialing 877-344-7529 (international: 412-317-0088) and using conference playback number 10027573.

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 Gathering LLC, 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, 2012.  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.

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

 

PVR PARTNERS, L.P.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - unaudited

(in thousands, except per unit data)


















Three Months Ended



March 31,



2013


2012

Revenues



     Natural gas 


$      87,714


$      74,627

     Natural gas liquids


100,508


117,794

     Gathering fees


22,916


7,463

     Trunkline  fees


21,101


6,392

     Coal royalties


22,951


33,159

     Other 


8,221


6,982

Total revenues


263,411


246,417






Expenses





     Cost of gas purchased


158,208


165,464

     Operating


15,370


15,903

     General and administrative


13,785


12,044

     Impairments


-


124,845

     Depreciation, depletion and amortization


44,786


23,853

Total expenses


232,149


342,109






Operating income (loss)


31,262


(95,692)






Other income (expense)





     Interest expense


(23,678)


(9,817)

     Derivatives


(441)


(4,951)

     Interest income and other


94


116

Net income (loss) 


$        7,237


$  (110,344)











Earnings (loss) per common unit, basic and diluted


$        (0.17)


$        (1.39)






Weighted average number of common units outstanding, basic


95,906


79,301

Weighted average number of common units outstanding, diluted 


95,906


79,340






Weighted average number of Class B units outstanding


22,618


-

Weighted average number of Special units outstanding


10,346


-











Other data by segment:










Eastern Midstream:





Gathered volumes (MMcfd)


584


210

Trunkline volumes (MMcfd) (1)


644


92

Midcontinent Midstream:





Daily throughput volumes (MMcfd) 


391


442

Coal and Natural Resource Management:





Coal royalty tons (in thousands)


6,446


8,105






(1) Trunkline volumes include a significant portion of gathered volumes.





 

PVR PARTNERS, L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS - unaudited

(in thousands)








March 31,


December 31,



2013


2012






Assets





     Cash and cash equivalents


$         12,973


$         14,713

     Accounts receivable


119,939


133,546

     Assets held for sale


-


11,450

     Other current assets


5,252


5,446

         Total current assets


138,164


165,155

     Property, plant and equipment, net


2,048,232


1,989,346

     Other long-term assets


844,052


844,208

          Total assets


$    3,030,448


$    2,998,709






Liabilities and Partners' Capital





     Accounts payable and accrued liabilities


$       164,492


$       197,034

     Deferred income


4,908


3,788

     Derivative liabilities


434


-

         Total current liabilities


169,834


200,822

     Other long-term liabilities


33,242


35,468

     Senior notes 


900,000


900,000

     Revolving credit facility


700,000


590,000

     Partners' capital


1,227,372


1,272,419

          Total liabilities and partners' capital


$    3,030,448


$    2,998,709

 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited

(in thousands)








Three Months Ended



March 31,



2013


2012

Cash flows from operating activities



     Net income (loss)


$           7,237


$      (110,344)

     Adjustments to reconcile net income (loss) to





          net cash provided by operating activities:





     Depreciation, depletion and amortization


44,786


23,853

     Impairments


-


124,845

     Commodity derivative contracts:





     Total derivative losses included in net income


441


4,951

     Cash payments to settle derivatives for the period


(222)


(3,641)

     Non-cash interest expense


1,652


1,049

     Non-cash unit-based compensation


1,264


2,038

     Equity earnings, net of distributions received


1,325


(741)

     Other


(2,004)


(647)

     Changes in operating assets and liabilities


24,936


3,804

Net cash provided by operating activities


79,415


45,167






Cash flows from investing activities





Acquisitions


(2,346)


(196)

Additions to property, plant and equipment


(138,446)


(75,373)

Joint venture capital contributions


(10,200)


(6,600)

Proceeds from sale of assets


11,964


-

Other


1,582


310

Net cash used in investing activities


(137,446)


(81,859)






Cash flows from financing activities





Distributions to partners


(52,735)


(40,418)

Proceeds from borrowings, net


110,000


76,000

Cash paid for debt issuance costs


(879)


-

Other


(95)


-

Net cash provided by financing activities


56,291


35,582






Net increase (decrease) in cash and cash equivalents


(1,740)


(1,110)

Cash and cash equivalents - beginning of period


14,713


8,640

Cash and cash equivalents - end of period


$         12,973


$           7,530

 

PVR PARTNERS, L.P.

CERTAIN NON-GAAP FINANCIAL MEASURES - unaudited

(in thousands)












Three Months Ended







March 31,


Guidance Range



2013


2012


Full Year 2013

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

















Segment Adjusted EBITDA (a):









Eastern Midstream


$      37,691


$        9,961


$  190,000


$  230,000

Midcontinent Midstream


15,704


12,323


70,000


80,000

Coal and Natural Resource Management


22,653


30,722


75,000


85,000

Total segment adjusted EBITDA


$      76,048


$      53,006


$  335,000


$  395,000

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









Depreciation, depletion and amortization


(44,786)


(23,853)


(180,000)


(190,000)

Impairments on PP&E and equity investments


-


(124,845)


-


-

Interest expense


(23,678)


(9,817)


(95,000)


(100,000)

Derivatives


(441)


(4,951)


-


-

Other


94


116


-


-

Net income (loss)


$        7,237


$  (110,344)


$    60,000


$  105,000










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









Net income (loss)


$        7,237


$  (110,344)





Depreciation, depletion and amortization


44,786


23,853





Impairments on PP&E and equity investments 


-


124,845





Derivative contracts:









  Derivative losses included in net income


441


4,951





  Cash payments to settle derivatives for the period


(222)


(3,641)





Equity earnings from joint ventures, net of distributions 


1,325


(741)





Maintenance capital expenditures


(3,664)


(3,097)














Distributable cash flow (b)


$      49,903


$      35,826














Distribution to Partners:


















Total cash distribution paid during the period


$      52,735


$      40,418














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









Net income (loss)


$        7,237


$  (110,344)





Impairments on PP&E and equity investments 


-


124,845





Adjustments for derivatives:









Derivative losses included in net income


441


4,951





Cash payments to settle derivatives for the period


(222)


(3,641)














Net income (loss), as adjusted (c)


$        7,456


$      15,811





 

(a) 

Segment Adjusted EBITDA, or earnings before interest, tax and depreciation, depletion and amortization ("DD&A"), represents operating income plus DD&A, plus impairments.  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 (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.  At management's discretion, a fixed amount of $1.8 million per quarter in 2013 and $1.3 million per quarter in 2012 has been included in maintenance capital for well connects. 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. For comparative purposes, prior year amounts exclude replacement capital expenditures.



(c) 

Net income, as adjusted, represents net income adjusted to exclude the effects of non-cash impairment charges and 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




March 31,




2013


2012


Revenues






     Gathering fees


$          22,138


$            4,919


     Trunkline fees


21,101


6,392


     Other


658


162


        Total revenues


43,897


11,473


Expenses






     Operating 


1,980


898


     General and administrative


4,226


614


     Depreciation, depletion and amortization


22,644


2,061


       Total expenses


28,850


3,573








Operating income 


$          15,047


$            7,900
















Midcontinent Midstream




Three Months Ended




March 31,




2013


2012


Revenues






     Natural gas


$          87,714


$          74,627


     Natural gas liquids


100,508


117,794


     Gathering fees


778


2,544


     Other 


1,143


617


        Total revenues


190,143


195,582


Expenses






     Cost of gas purchased


158,208


165,464


     Operating 


10,354


11,227


     General and administrative


5,877


6,568


     Impairments


-


124,845


     Depreciation, depletion and amortization


14,906


13,606


       Total expenses


189,345


321,710








Operating income (loss) 


$               798


$      (126,128)





















Coal and Natural Resource Management



Three Months Ended




March 31,




2013


2012


Revenues






     Coal royalties


$          22,951


$          33,159


     Coal services


1,161


1,238


     Timber


1,432


1,520


     Oil and gas royalties


655


683


     Other


3,172


2,762


        Total revenues


29,371


39,362


Expenses






     Operating 


3,036


3,778


     General and administrative


3,682


4,862


     Depreciation, depletion and amortization


7,236


8,186


       Total expenses


13,954


16,826








Operating income


$          15,417


$          22,536


 

PVR PARTNERS, L.P.

DERIVATIVE CONTRACT SUMMARY - unaudited

As of March 31, 2013










Average

Volume Per

Day












Swap





Price








Crude oil swap (WTI)


 (barrels) 


(per barrel)


Second quarter through the fourth quarter 2013


500


$94.80








Natural gas swaps (1)


 (MMBtu) 


(per MMBtu)


Second quarter through the fourth quarter 2013


5,500


$3.823


 

Our exposure profile with respect to commodity prices depends on many factors, including inlet volumes, plant operational efficiencies, contractual terms, and the price relationship between ethane and natural gas.

We anticipate operating our plants in "ethane rejection" for the entirety of 2013. Under this operational mode, we estimate that for every $1.00 per MMBtu change in the natural gas price, our natural gas midstream gross margin and operating income for the remainder of 2013 would change by $6.6 million, excluding the effect of the natural gas hedges described above, and all other factors remaining constant. The natural gas hedges described above would reduce the net impact to $5.1 million.

Similarly, for every $5.00 per barrel change in crude oil prices, with all other factors remaining constant, and excluding the effect of the 2013 crude oil derivative described above, we estimate that our natural gas midstream gross margin and operating income would change by $1.3 million. The crude oil hedge described above would reduce the net impact to $0.6 million.

For every $0.10 per gallon increase in the price of ethane with all other factors remaining constant, we estimate that our gross margin and operating income will decrease by $3.2 million while operating in ethane rejection. Finally, for every $0.10 per gallon increase in the price of other NGLs with all other factors remaining constant, we estimate that our gross margin and operating income will increase by $3.1 million.

(1) The natural gas swaps settle against the monthly index price reported in Inside FERC's Natural Gas Market Report for Southern Star Central Gas Pipeline (Texas, Oklahoma, Kansas), which has historically tended to be settled at a lower price than the Henry Hub national benchmark. A significant portion of our physical gas sales are also priced using this reported monthly index.

 

PVR PARTNERS, L.P.

OPERATING STATISTICS

($ Amounts in 000s)








Three Months Ended


March 31,


 December 31,


2013


2012


2012

EASTERN MIDSTREAM












Volumes (MMcfd)






Lycoming Trunkline

336


92


200

Wyoming Trunkline

308


-


205

Total Trunkline Volume

644


92


405







Lycoming Gathering

223


92


246

Wyoming Gathering

192


118


205

East Lycoming Gathering

118


-


92

Bradford Gathering

47


-


15

Greene Gathering

4


-


4

Total Gathering

584


210


562

Total Throughput

1,228


302


967







Total Trunkline Fees

$           21,101


$             6,392


$           18,609

Total Gathering Fees

$           22,138


$             4,919


$           18,658







Trunkline Fees / Mcf

$               0.36


$               0.76


$               0.50

Gathering Fees / Mcf

$               0.42


$               0.26


$               0.36

 

PVR PARTNERS, L.P.

OPERATING STATISTICS

($ Amounts in 000s)








Three Months Ended


March 31,


December 31,


2013


2012


2012

MIDCONTINENT MIDSTREAM












Volumes (MMcfd)






Panhandle System

340


336


369

Crossroads System (1)

-


57


-

Crescent System

28


21


28

Hamlin System

6


7


6

Total Processing Systems

374


421


403







Arkoma System

9


10


9

North Texas System

8


11


9

Total Gathering Only Systems

17


21


18







Total All Systems

391


442


421







Total Gathering and Processing Fees, Net(2)

$           30,792


$           29,501


$           32,115

Fees Per Mcf

$               0.88


$               0.73


$               0.83







(1) Crossroads System was sold July 3, 2012

(2) Processing fees include revenues from natural gas,  natural gas liquids and gathering fees less cost of gas purchased

 

PVR PARTNERS, L.P.

OPERATING STATISTICS

($ Amounts in 000s)








Three Months Ended


March 31,


December 31,


2013


2012


2012

COAL PRODUCTION












Coal royalty tons by region (000s)






Central Appalachia

2,617


4,068


2,831

Northern Appalachia

776


798


1,093

Illinois Basin

671


1,137


781

San Juan Basin

2,382


2,102


1,925

Total Tons

6,446


8,105


6,630







Total Coal Royalties

$           22,951


$           33,159


$           22,983







Average Coal Royalty per ton

$               3.56


$               4.09


$               3.47

 

 

SOURCE PVR Partners, L.P.



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