PXP Announces Strong First Quarter Financial & Operating Results, Reports Substantial Progress in its Gulf of Mexico Business Expansion, and Delivers Exceptional Eagle Ford Field Development Results

PR Newswire

HOUSTON, May 2, 2013 /PRNewswire/ -- Plains Exploration & Production Company (PXP) ("PXP" or the "Company") announces 2013 first-quarter financial and operating results.

2013 HIGHLIGHTS

  • Total daily sales volumes averaged 170.4 thousand barrels of oil equivalent ("BOE"), a 92% increase per diluted share compared to first-quarter 2012.
  • Oil daily sales volumes averaged 129.2 thousand barrels, a 158% increase per diluted share compared to first-quarter 2012.
  • Phobos discovery well announced, encountering approximately 250 net feet of high-quality lower Tertiary oil pay in the Gulf of Mexico.
  • Total revenues were $1,232 million compared to $524.3 million in the first-quarter of 2012.
  • Net cash provided by operating activities was $818.7 million compared to $335.4 million in the first-quarter of 2012.
  • Operating cash flow (a non-GAAP measure) was $789.6 million compared to $329.2 million in the first-quarter of 2012.
  • Long-term debt, including current maturities, was reduced by $420 million to approximately $9.7 billion at quarter-end 2013 compared to approximately $10.1 billion at year-end 2012.
  • Income from operations was $397.3 million compared to $171.3 million in the first-quarter of 2012.
  • Net income attributable to common stockholders was $22.6 million, or $0.17 per diluted share compared to a first-quarter 2012 net loss attributable to common stockholders of $82.3 million, or $0.64 per diluted share.
  • Adjusted net income attributable to common stockholders (a non-GAAP measure) was $139.6 million, or $1.05 per diluted share, compared to first-quarter 2012 adjusted net income attributable to common stockholders of $77.0 million, or $0.58 per diluted share.

FINANCIAL SUMMARY

PXP reported first-quarter revenues of $1.2 billion and net income attributable to common stockholders of $22.6 million, or $0.17 per diluted share, compared to revenues of $524.3 million and a net loss attributable to common stockholders of $82.3 million, or $0.64 per diluted share, for the first-quarter of 2012.

The first-quarter 2013 net income attributable to common stockholders includes certain items affecting the comparability of operating results. Those items consist of realized and unrealized gains and losses on our mark-to-market derivative contracts resulting in a net loss of $202.0 million due in large part to higher crude oil forward prices, a $15.5 million unrealized gain on investment in McMoRan Exploration Co. ("McMoRan") common stock, debt extinguishment costs of $18.1 million, and other items. When considering these items, PXP reports adjusted net income attributable to common stockholders of $139.6 million, or $1.05 per diluted share (a non-GAAP measure), compared to $77.0 million, or $0.58 per diluted share, for the same period in 2012.

A reconciliation of non-GAAP financial measures used in this release to comparable GAAP financial measures is included with the financial tables.

OPERATIONAL UPDATE

PXP's 2013 first-quarter daily sales volumes averaged 170.4 thousand BOE per day compared to 87.9 thousand BOE in the first-quarter of 2012.

Crude oil sales volumes averaged 118.9 thousand barrels per day, compared to first-quarter 2012 average volumes of 47.8 thousand barrels per day. Volume growth is driven primarily by the addition of the deepwater Gulf of Mexico assets acquired in November 2012 and strong Eagle Ford Field performance.

Natural gas liquids sales volumes averaged 10.3 thousand barrels per day, compared to first-quarter 2012 average volumes of 1.8 thousand barrels per day. The increase reflects the addition of the deepwater Gulf of Mexico assets and strong Eagle Ford Field performance.

Natural gas sales volumes averaged 246.9 million cubic feet ("MMcf") per day compared to 229.3 MMcf per day in the first-quarter 2012. The increase reflects the addition of the deepwater Gulf of Mexico assets and increased production from the Eagle Ford Field, partially offset by decreased production from the Haynesville Field.

In the Gulf of Mexico, first-quarter daily sales volumes averaged 60.7 thousand BOE per day net to PXP. The Company closed the acquisition of interests in certain deepwater Gulf of Mexico oil and gas properties in late 2012. In early 2013, PXP acquired lease blocks near its newly acquired infrastructure and secured drilling rig capacity to accelerate its top-tier deepwater Gulf of Mexico program beginning in the second half of 2014. There have been additional producer wells drilled at Lucius and a significant discovery was announced at Phobos.

At the Lucius development in Keathley Canyon, four of the six planned producer wells have been drilled with two producer wells remaining to drill this year. In December 2011, the operator and its working interest partners sanctioned development of Lucius, a subsea development consisting of a truss spar hull located in 7,200 feet of water with a topside capacity of 80 thousand barrels of oil per day and 450 MMcf of gas per day. First production is anticipated in 2014. Anadarko Petroleum Corporation is the operator. PXP has a 23.33% working interest.

At the Phobos prospect, located in Sigsbee Escarpment block 39, the operator and its partners recently announced a discovery at the Phobos-1 well which encountered approximately 250 net feet of high-quality oil pay in Lower Tertiary-aged reservoirs. The Phobos discovery was drilled to a total depth of 28,675 feet in approximately 8,500 feet of water, approximately 11 miles south of the Lucius development. Anadarko Petroleum Corporation is the operator and is currently incorporating the data from the Phobos well to determine future activities. PXP has a 50% working interest.

In March 2013, PXP participated in the Gulf of Mexico Outer Continental Shelf Lease Sale 227 and was the apparent high bidder on 11 deepwater blocks. Of the 11 blocks, 7 blocks are located near PXP's Holstein Hub and 3 blocks are located near PXP's Horn Mountain Hub. The sum of PXP's high bids was approximately $82.6 million. If all high bids are awarded, the Company's deepwater Gulf of Mexico portfolio will include interests in 152 blocks containing 60 prospects or leads in the Pliocene, Miocene, Tertiary and Cretaceous reservoirs. PXP has also contracted for two latest-generation, ultra-deep capable drill ships to accelerate the expansion of the Company's deepwater Gulf of Mexico program. The Noble Sam Croft drill ship and the Noble Tom Madden drill ship are currently under construction with delivery to PXP expected mid-year 2014 and early 2015, respectively.

PXP has been notified that the Pascagoula Gas Processing Plant, located in Pascagoula, Mississippi, operated by BP America Corporation and responsible for processing production from wells in the eastern corridor of the deepwater Gulf of Mexico, will shut down for approximately 36 days starting on or about May 3, 2013 during which time required maintenance will be performed. This activity will disrupt processing system wide from several operators, including PXP. The PXP operated Horn Mountain platform and the PXP operated Marlin Hub will be impacted by the work at the gas processing plant. PXP holds a 100% working interest in the Horn Mountain and Marlin Fields. Oil and gas production could be shut-in while the gas processing plant undergoes its required maintenance. PXP's net average daily sales volumes from these facilities were 44.0 thousand BOE per day in the first quarter of 2013.

Despite the second-quarter impact on sales volumes from the required plant shut down, PXP maintains its total company full-year 2013 oil and natural gas sales volume mid-point guidance of 156.3 thousand BOE per day.

In the Eagle Ford Field, first-quarter daily sales volumes averaged 44.7 thousand BOE per day net to PXP compared to first-quarter 2012 average daily sales volumes of 13.9 thousand BOE per day net to PXP. At the end of March, PXP had 7 drilling rigs operating and 31 wells drilled but waiting on completion or connection to pipelines.

In California, first-quarter daily sales volumes averaged 37.2 thousand BOE per day net to PXP compared to the first-quarter 2012 daily sales volume average of 38.6 thousand BOE per day net to PXP. At the end of March, PXP had 4 drilling rigs operating onshore.

In the Haynesville Field, first-quarter daily sales volumes averaged 134.2 MMcf per day net to PXP compared to first-quarter 2012 average daily sales volumes of 173.5 MMcf per day net to PXP. The sales volume decline reflects significantly lower drilling activity. At the end of March, there were 4 drilling rigs operating in which PXP had a working interest.

CAPITAL SPENDING

For the first-quarter of 2013, PXP had cash expenditures of approximately $499.5 million for additions to oil and gas properties and leasehold acquisitions of which $106.1 million was funded by Plains Offshore Operations Inc., PXP's consolidated subsidiary.

COMMODITY PRICES

During the first-quarter of 2013, Brent crude oil price averaged $112.60 per barrel compared to $118.42 per barrel in the first-quarter 2012. PXP's 2013 first-quarter crude oil average realized price per barrel before derivative transactions was $105.16 per barrel, or approximately 93% of Brent, compared to $105.87 per barrel in the first-quarter 2012, or approximately 89% of Brent. Including the impact of derivative transactions, the first-quarter 2013 crude oil average realized price was $102.45 per barrel, or approximately 91% of Brent, compared to $104.38 per barrel in the first-quarter 2012, or 88% of Brent.

During the first-quarter of 2013, the oil average realized price per barrel before derivative transactions, which includes 10.3 thousand barrels per day net to PXP of natural gas liquids, was $99.60 per barrel, or approximately 88% of Brent, compared to $103.45 per barrel in the first-quarter 2012, or 87% of Brent. Including the impact of derivative transactions, the average realized price in the first-quarter 2013 was $97.10 per barrel, or 86% of Brent, compared to $102.01 per barrel in the first-quarter 2012, or 86% of Brent.

During the first-quarter of 2013, NYMEX gas price averaged $3.34 per million British thermal units ("MMBtu") compared to $2.73 per MMBtu in the first-quarter 2012. PXP's 2013 first-quarter natural gas average realized price before derivative transactions was $3.25 per MMBtu, or approximately 97% of NYMEX, compared to $2.56 per MMBtu in the first-quarter 2012, or 94% of NYMEX. Including the impact of derivative transactions, the average realized price in the first-quarter 2013 was $3.67 per MMBtu, or approximately 110% of NYMEX, compared to $3.29 per MMBtu in the first-quarter 2012, or 121% of NYMEX.

MANAGEMENT COMMENT

James C. Flores, Chairman, President and CEO of PXP commented, "The first quarter results confirm the strong growth we have been projecting. Production, revenues, net cash provided by operating activities and earnings saw significant increases during the quarter led by the high rate-of-return crude oil production in the deepwater Gulf of Mexico, the Eagle Ford Field, and California. Our diversified growth strategy, underpinned by a unique combination of oil and natural gas assets and our on-going risk management program, remains our competitive advantage. The Company is centered on executing its highly profitable, lower-risk, long-term, oil-focused growth plan which is complementary to the growth profile and cash margins of the large, low-cost, expandable asset base characteristics of Freeport-McMoRan Copper & Gold Inc. with whom we have entered into a merger transaction."

CONFERENCE CALL

PXP will host a conference call today, Thursday, May 2, at 8:00 a.m. Central time. Investors wishing to participate in the conference call may dial 1-800-567-9836 or 1-973-935-8460. The conference call and replay ID is: 36577090. The replay can be accessed by dialing 1-855-859-2056 or 1-404-537-3406. A live webcast of the conference call will be available in the Investor Information section of PXP's website at www.pxp.com.  

PXP is an independent oil and gas company primarily engaged in the activities of acquiring, developing, exploring and producing oil and gas in California, Texas, Louisiana, and the Gulf of Mexico. PXP is headquartered in Houston, Texas.

ADDITIONAL INFORMATION & FORWARD-LOOKING STATEMENTS
This press release contains forward-looking information regarding PXP that is intended to be covered by the safe harbor for "forward-looking statements" provided by the Private Securities Litigation Reform Act of 1995. All statements included in this press release that address activities, events or developments that PXP expects, believes or anticipates will or may occur in the future are forward-looking statements.

These include statements regarding:

  • completion of the proposed merger,
  • reserve and production estimates,
  • oil and gas prices,
  • the impact of derivative positions,
  • production expense estimates,
  • cash flow estimates,
  • future financial performance,
  • capital and credit market conditions,
  • planned capital expenditures, and
  • other matters that are discussed in PXP's filings with the SEC.

These statements are based on our current expectations and projections about future events and involve known and unknown risks, uncertainties, and other factors that may cause our actual results and performance to be materially different from any future results or performance expressed or implied by these forward-looking statements. Please refer to our filings with the SEC, including our Form 10-K and Forms 10-Q, for a discussion of these risks.

References to quantities of oil or natural gas may include amounts that the Company believes will ultimately be produced, but that are not yet classified as "proved reserves" under SEC definitions. In this press release, the Company uses the terms "possible reserves" and "resource potential" to describe the Company's internal estimates of volumes of oil and gas that are not classified as proved reserves but are potentially recoverable through exploratory drilling or additional drilling or recovery techniques.  Resource potential is a broader description of potentially recoverable volumes than probable and possible reserves, as defined by the SEC regulations. SEC guidelines prohibit us from including resource potential in filings with the SEC. References in this press release to oil include crude oil, condensate, and natural gas liquid volumes.

All forward-looking statements in this press release are made as of the date hereof, and you should not place undue reliance on these statements without also considering the risks and uncertainties associated with these statements and our business that are discussed in this press release and our other filings with the SEC. Moreover, although we believe the expectations reflected in the forward-looking statements are based upon reasonable assumptions, we can give no assurance that we will attain these expectations or that any deviations will not be material. Except as required by law, we do not intend to update these forward-looking statements and information.

IMPORTANT ADDITIONAL INFORMATION ABOUT THE PROPOSED MERGER AND WHERE TO FIND IT:

In connection with the proposed business combination transaction between PXP and FCX, FCX has filed with the SEC a registration statement on Form S-4 that contains a definitive proxy statement of PXP that also constitutes a prospectus of FCX. THE REGISTRATION STATEMENT AND THE PROXY STATEMENT/PROSPECTUS CONTAIN IMPORTANT INFORMATION ABOUT PXP, FCX, THE PROPOSED TRANSACTION AND RELATED MATTERS. INVESTORS AND SECURITY HOLDERS ARE URGED TO READ THE REGISTRATION STATEMENT AND THE PROXY STATEMENT/PROSPECTUS CAREFULLY. Investors and security holders may obtain free copies of the registration statement and the proxy statement/prospectus and other documents filed with the SEC by PXP and FCX through the web site maintained by the SEC at www.sec.gov. In addition, investors and security holders may obtain free copies of the registration statement and the proxy statement/prospectus by phone, e-mail or written request by contacting the investor relations department of PXP or FCX at the following:

Plains Exploration & Production Company
700 Milam, Suite 3100
Houston, TX 77002
Attention: Investor Relations
Phone: (713) 579-6000
Email: investor@pxp.com

Freeport-McMoRan Copper & Gold Inc.
333 N. Central Ave.
Phoenix, AZ 85004
Attention: Investor Relations
Phone: (602) 366-8400
Email: ir@fmi.com

PARTICIPANTS IN THE SOLICITATION

PXP and FCX, and their respective directors and executive officers, may be deemed to be participants in the solicitation of proxies in respect of the proposed transactions contemplated by the merger agreement. Information regarding directors and executive officers of PXP is contained in the proxy statement/prospectus dated April 18, 2013, which is filed with the SEC. Information regarding FCX's directors and executive officers is contained in FCX's definitive proxy statement dated April 27, 2012, which is filed with the SEC.

This document shall not constitute an offer to sell or the solicitation of an offer to buy any securities, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the U.S. Securities Act of 1933, as amended.

 

Plains Exploration & Production Company

Consolidated Statements of Income

(in thousands, except per share data)








Three Months Ended



March 31,



2013


2012



 (Unaudited) 

Revenues





Oil sales

$ 1,158,438


$ 467,488


Gas sales 

72,331


53,524


Other operating revenues

1,346


3,263



1,232,115


524,275

Costs and Expenses





Lease operating expenses

170,233


83,006


Steam gas costs

14,604


11,124


Electricity

11,056


11,374


Production and ad valorem taxes

28,632


12,631


Gathering and transportation expenses

22,618


16,272


General and administrative





G&A

44,765


38,382


Acquisition and merger related costs

1,199


-


Depreciation, depletion and amortization

530,460


177,697


Accretion

10,015


3,753


Other operating expense (income)

1,196


(1,261)



834,778


352,978






Income from Operations

397,337


171,297

Other (Expense) Income





Interest expense

(140,998)


(45,253)


Debt extinguishment costs

(18,053)


-


Loss on mark-to-market derivative contracts

(202,023)


(109,050)


Gain (loss) on investment measured at fair value

15,544


(135,930)


Other income (expense)

395


(405)

Income (Loss) Before Income Taxes 

52,202


(119,341)


Income tax (expense) benefit





Current

(4,790)


(19)


Deferred

(15,618)


46,057

Net Income (Loss)

31,794


(73,303)


Net income attributable to noncontrolling interest
   in the form of preferred stock of subsidiary

(9,209)


(9,016)

Net Income (Loss) Attributable to Common Stockholders

$      22,585


$ (82,319)






Earnings (Loss) per Common Share





Basic

$          0.17


$     (0.64)


Diluted

$          0.17


$     (0.64)

Weighted Average Common Shares Outstanding





Basic

130,284


129,348


Diluted

132,930


129,348






 


Plains Exploration & Production Company

Operating Data





Three Months Ended





March 31,





2013


2012





(Unaudited)

Daily Average Volumes





Oil and liquids sales (Bbls)

129,233


49,657


Gas (Mcf)






Production

250,044


234,001



Used as fuel

3,140


4,705



Sales 

246,904


229,296


BOE






Production

170,907


88,657



Sales 

170,384


87,873

Unit Economics (in dollars) 





Average Index Prices






ICE Brent Price per Bbl

$   112.60


$   118.42



NYMEX Price per Bbl

94.36


103.03



NYMEX Price per Mcf

3.34


2.73


Average Realized Sales Price Before Derivative Transactions






Oil (per Bbl)

$     99.60


$   103.45



Gas (per Mcf)

3.25


2.56



Per BOE

80.26


65.16


Cash Margin per BOE (1)






Oil and gas revenues 

$     80.26


$     65.16



Costs and expenses






   Lease operating expenses

(11.10)


(10.38)



   Steam gas costs

(0.95)


(1.39)



   Electricity

(0.72)


(1.42)



   Production and ad valorem taxes

(1.87)


(1.58)



   Gathering and transportation

(1.47)


(2.03)



   Oil and gas related DD&A

(33.81)


(21.64)



Gross margin (GAAP)

30.34


26.72




Oil and gas related DD&A

33.81


21.64




Realized (loss) gain on derivative instruments

(1.29)


1.08



Cash margin (non-GAAP)

$     62.86


$     49.44








Oil and gas capital expenditures accrued ($ in thousands) (2)

$ 472,711


$ 439,939








(1)

Cash margin per BOE (a non-GAAP measure) is calculated by adjusting gross margin per BOE (a GAAP measure) to include the realized gain and loss on derivative instruments and to exclude DD&A.  Management believes this presentation may be helpful to investors as it represents the cash generated by our oil and gas production that is available for, among other things, capital expenditures and debt service.  PXP management uses this information to analyze operating trends for comparative purposes within the industry.  This measure is not intended to replace the GAAP statistic but rather to provide additional information that may be helpful in evaluating trends and performance.  








(2)

Additions to oil and gas properties reported in our consolidated statement of cash flows differ from the accrual basis amounts reflected above due to the timing of cash payments.  Excludes acquisitions.








 


Plains Exploration & Production Company


Reconciliation of GAAP to Non-GAAP Measure

















Three Months Ended March 31, 2013



Oil


Gas


BOE



(per Bbl)


(per Mcf)



Average Realized Sales Price 













Average realized price before derivative instruments (GAAP)  (1)

$   99.60


$     3.25


$ 80.26


Realized (loss) gain on derivative instruments

(2.50)


0.42


(1.29)








Realized cash price including derivative settlements (non-GAAP)

$   97.10


$     3.67


$ 78.97

















Three Months Ended March 31, 2012



Oil


Gas


BOE



(per Bbl)


(per Mcf)



Average Realized Sales Price













Average realized price before derivative instruments (GAAP)  (1)

$ 103.45


$     2.56


$ 65.16


Realized (loss) gain on derivative instruments

(1.44)


0.73


1.08








Realized cash price including derivative settlements (non-GAAP)

$ 102.01


$     3.29


$ 66.24
























(1)

Excludes the impact of production costs and expenses and DD&A.

 

Plains Exploration & Production Company

Consolidated Statements of Cash Flows

(in thousands of dollars)


Three Months Ended


March 31,


2013


2012


(Unaudited)

CASH FLOWS FROM OPERATING ACTIVITIES




Net income (loss)

$     31,794


$    (73,303)

Items not affecting cash flows from operating activities




Depreciation, depletion, amortization and accretion

540,475


181,450

Deferred income tax expense (benefit)

15,618


(46,057)

Debt extinguishment costs

(4,903)


-

Loss on mark-to-market derivative contracts

202,023


109,050

(Gain) loss on investment measured at fair value

(15,544)


135,930

Non-cash compensation

13,496


18,232

Other non-cash items

2,706


1,421

Change in assets and liabilities from operating activities

33,058


8,688

Net cash provided by operating activities

818,723


335,411

CASH FLOWS FROM INVESTING ACTIVITIES




Additions to oil and gas properties

(467,737)


(401,311)

Acquisition of oil and gas properties 

(31,748)


(16,573)

Proceeds from sales of oil and gas properties, net of
   costs and expenses

-


42,656

Derivative settlements

(13,516)


9,321

Additions to other property and equipment

(7,909)


(2,904)

Other 

(681)


-

Net cash used in investing activities

(521,591)


(368,811)

CASH FLOWS FROM FINANCING ACTIVITIES




Borrowings from revolving credit facilities

3,328,700


2,515,500

Repayments of revolving credit facilities

(3,573,500)


(2,440,500)

Principal payments of long-term debt

(171,180)


-

Costs incurred in connection with financing arrangements

(697)


(125)

Purchase of treasury stock

-


(88,490)

Distributions to holders of noncontrolling interest in the
   form of preferred stock of subsidiary

(6,750)


(6,750)

Net cash used in financing activities

(423,427)


(20,365)

Net decrease in cash and cash equivalents

(126,295)


(53,765)

Cash and cash equivalents, beginning of period

180,565


419,098

Cash and cash equivalents, end of period

$     54,270


$   365,333





 

 

Plains Exploration & Production Company

Consolidated Balance Sheets

(in thousands of dollars)



March 31,


December 31,



2013


2012


ASSETS

(Unaudited)



Current Assets





Cash and cash equivalents

$        54,270


$       180,565


Accounts receivable

563,313


584,722


Commodity derivative contracts

2,892


56,208


Inventories

33,830


27,672


Investment

833,767


818,223


Deferred income taxes

227,051


150,876


Prepaid expenses and other current assets

45,062


21,464



1,760,185


1,839,730

Property and Equipment, at cost





Oil and natural gas properties - full cost method






Subject to amortization                                                    

19,236,999


18,814,337



Not subject to amortization

3,700,129


3,631,475


Other property and equipment

164,890


153,344






23,102,018


22,599,156


Less allowance for depreciation, depletion, amortization and impairment

(8,392,756)


(7,870,356)



14,709,262


14,728,800

Goodwill

535,140


535,140

Commodity Derivative Contracts

-


903

Other Assets

185,787


193,710



$ 17,190,374


$  17,298,283







LIABILITIES AND EQUITY




Current Liabilities





Accounts payable

$      421,405


$       431,422


Commodity derivative contracts

62,569


18,942


Royalties and revenues payable

165,520


139,717


Interest payable

142,285


105,440


Other current liabilities

113,384


120,192


Current maturities of long-term debt

164,288


164,288



1,069,451


980,001

Long-Term Debt

9,559,247


9,979,369






Other Long-Term Liabilities





Asset retirement obligation

579,089


565,989


Commodity derivative contracts

118,427


26,810


Other

17,837


19,105



715,353


611,904

Deferred Income Taxes

1,863,678


1,770,568

Equity




Stockholders' equity





Common stock

1,439


1,439


Additional paid-in capital

3,413,932


3,437,826


Retained earnings

658,772


637,411


Treasury stock, at cost

(533,920)


(560,198)



3,540,223


3,516,478

Noncontrolling interest 




    Preferred stock of subsidiary

442,422


439,963



3,982,645


3,956,441



$ 17,190,374


$  17,298,283









 

 

Plains Exploration & Production Company

Summary of Open Derivative Positions

At May 1, 2013






















Average






Instrument


Daily


Average


Deferred



Period (1)


Type


Volumes


Price (2)


Premium


Index

Sales of Crude Oil Production


2013












May - Dec


Swap contracts(3)


40,000 Bbls


$109.23


-


Brent


May - Dec


Put options(4)


13,000 Bbls


$100.00 Floor with an $80.00 Limit


$6.800 per Bbl


Brent


May - Dec


Three-way collars(5)


25,000 Bbls


$100.00 Floor with an $80.00 Limit


-


Brent








$124.29 Ceiling






May - Dec


Three-way collars(5)


5,000 Bbls


$90.00 Floor with a $70.00 Limit


-


Brent








$126.08 Ceiling






May - Dec


Put options(4)


17,000 Bbls


$90.00 Floor with a $70.00 Limit


$6.253 per Bbl


Brent













2014












Jan - Dec


Put options(4)


5,000 Bbls


$100.00 Floor with an $80.00 Limit


$7.110 per Bbl


Brent


Jan - Dec


Put options(4)


30,000 Bbls


$95.00 Floor with a $75.00 Limit


$6.091 per Bbl


Brent


Jan - Dec


Put options(4)


75,000 Bbls


$90.00 Floor with a $70.00 Limit


$5.739 per Bbl


Brent













2015












Jan - Dec


Put options(4)


84,000 Bbls


$90.00 Floor with a $70.00 Limit


$6.889 per Bbl


Brent













Sales of Natural Gas Production




2013












May - Dec


Swap contracts(3)


110,000 MMBtu


$4.27


-


Henry Hub













2014












Jan - Dec


Swap contracts(3)


100,000 MMBtu


$4.09


-


Henry Hub



(1)

All of our derivatives are settled monthly.

(2)

The average strike prices do not reflect any premiums to purchase the put options.

(3)

If the index price is less than the fixed price, we receive the difference between the fixed price and the index price.  We pay the difference between the index price and the fixed price if the index price is greater than the fixed price.

(4)

If the index price is less than the per barrel floor, we receive the difference between the per barrel floor and the index price up to a maximum of $20 per barrel less the option premium.  If the index price is at or above the per barrel floor, we pay only the option premium.

(5)

If the index price is less than the per barrel floor, we receive the difference between the per barrel floor and the index price up to a maximum of $20 per barrel.  We pay the difference between the index price and the per barrel ceiling if the index price is greater than the per barrel ceiling.  If the index price is at or above the per barrel floor but at or below the per barrel ceiling, no cash settlement is required.

 

 


Derivative Settlements 

(in thousands of dollars)



The following table reflects cash (payments) receipts for derivatives attributable to the stated production periods.








Three Months Ended



March 31,



2013


2012






Oil sales 


$               (29,086)


$            (6,509)

Natural gas sales


9,225


15,177



$               (19,861)


$             8,668






 

 



Plains Exploration & Production Company

Reconciliation of GAAP to Non-GAAP Measure






The following table reconciles net income (loss) (GAAP) to adjusted net income and adjusted net income attributable to common stockholders (non-GAAP) for the three months ended March 31, 2013 and 2012. Adjusted net income and adjusted net income attributable to common stockholders exclude certain items affecting the comparability of operating results and the related tax effects.  Management believes this presentation may be helpful to investors.  PXP management uses this information to analyze operating trends and for comparative purposes within the industry. This measure is not intended to replace the GAAP statistic but rather to provide additional information that may be helpful in evaluating the Company's operational trends and performance.








Three Months Ended



March 31,



2013


2012



(millions of dollars)






Net income (loss) (GAAP)

$   31.8


$ (73.3)


Unrealized loss on mark-to-market derivative contracts

202.0


109.1


Realized (loss) gain on mark-to-market derivative contracts (1)

(19.9)


8.7


Unrealized (gain) loss on investment measured at fair value

(15.5)


135.9


Debt extinguishment costs

18.1


-


Acquisition and merger related costs

1.2


-


Adjust income taxes (2)

(68.9)


(94.4)






 Adjusted net income (non-GAAP) 

$ 148.8


$  86.0


 Net income attributable to noncontrolling interest in the form
   of preferred stock of subsidiary 

(9.2)


(9.0)

 Adjusted net income attributable to common stockholders (non-GAAP) 

$ 139.6


$  77.0
















(1)

The amounts presented in the above table differ from the adjustments reflected in the calculation of operating cash flow on the following page due to the accrued amounts reflected in the income statement versus the actual cash received or paid reflected in the consolidated statement of cash flows. 






(2)

Tax rates assumed based upon adjusted earnings are 38% and 36% for the three months ended March 31, 2013 and 2012, respectively. Tax rates exclude the effects of nonrecurring tax related expenses and benefits.

 


Plains Exploration & Production Company

Reconciliation of GAAP to Non-GAAP Measure













The following table reconciles Net Cash Provided by Operating Activities (GAAP) to Operating Cash Flow (non-GAAP) for the three months ended March 31, 2013 and 2012.  Management believes this presentation may be useful to investors.  PXP management uses this information for comparative purposes within the industry and as a means of measuring the Company's ability to fund capital expenditures and service debt. This measure is not intended to replace the GAAP statistic but rather to provide additional information that may be helpful in evaluating the Company's operational trends and performance.







Operating cash flow is calculated by adjusting net income to add back certain non-cash and non-operating items, including debt extinguishment costs, the unrealized gain and loss on mark-to-market derivative contracts, to include derivative cash settlements for the realized gain and loss on mark-to-market derivative contracts that are classified as investing activities for GAAP purposes, to exclude the unrealized gain and loss on the investment measured at fair value, to include distributions to holders of noncontrolling interest in the form of preferred stock of subsidiary that are classified as financing activities for GAAP purposes and to exclude certain other items.  










Three Months Ended




March 31,




2013


2012




(millions of dollars)


Net income (loss)

$   31.8


$ (73.3)


Items not affecting operating cash flows





  Depreciation, depletion, amortization and accretion

540.5


181.4


  Deferred income tax expense (benefit)

15.6


(46.0)


  Debt extinguishment costs

18.1


-


  Unrealized loss on mark-to-market derivative contracts

202.0


109.1


  Unrealized (gain) loss on investment measured at fair value

(15.5)


135.9


  Acquisition and merger related costs

1.2


-


  Non-cash compensation

13.5


18.2


  Other non-cash items

2.7


1.4


Realized (loss) gain on mark-to-market derivative contracts

(13.5)


9.3


Distributions to holders of noncontrolling interest in the 





   form of preferred stock of subsidiary

(6.8)


(6.8)








Operating cash flow (non-GAAP)

$ 789.6


$ 329.2














Reconciliation of non-GAAP to GAAP measure






Operating cash flow (non-GAAP)

$ 789.6


$ 329.2



Changes in assets and liabilities from operating activities

33.0


8.7



Realized loss (gain) on mark-to-market derivative contracts

13.5


(9.3)



Acquisition and merger related costs

(1.2)


-



Cash portion of debt extinguishment costs

(23.0)


-



Distributions to holders of noncontrolling interest in the 






   form of preferred stock of subsidiary

6.8


6.8








Net cash provided by operating activities (GAAP)

$ 818.7


$ 335.4







 

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