|  April 21, 2014  |  
Mostly Cloudy   45.0F  |  Forecast »
Bookmark and Share Email this page Email Print this page Print Feed Feed

Pioneer Natural Resources Reports Third Quarter 2010 Financial and Operating Results

DALLAS--(BUSINESS WIRE)--Pioneer Natural Resources Company (NYSE:PXD) ("Pioneer" or "the Company") today announced financial and operating results for the quarter ended September 30, 2010.

Pioneer reported third quarter net income attributable to common stockholders of $112 million, or $.94 per diluted share (see attached schedule for a description of the earnings per diluted share calculation). Net income included unrealized mark-to-market gains on derivatives of $63 million after tax, or $.53 per diluted share. Without the effect of this item, adjusted income for the third quarter of 2010 would have been $49 million, or $.41 per diluted share.

Also included in Pioneer's third quarter results was a net gain of $7 million after tax, or $.06 per diluted share, related to unusual items. These unusual items included:

  • Alaska Petroleum Production Tax (PPT) credits of $8 million after tax ($.06 per diluted share),
  • a net hurricane-related insurance recovery of $2 million after tax ($.02 per diluted share), primarily related to reclamation work required at Pioneer's East Cameron 322 Gulf of Mexico property that was destroyed by Hurricane Rita in 2005,
  • income related to discontinued operations in the Gulf of Mexico and Argentina of $1 million after tax ($.01 per diluted share), offset by
  • a $4 million after tax charge ($.03 per diluted share) to reduce the carrying value of unused dry gas well pipe inventory to its estimated net realizable value.
Third quarter and other recent highlights included:

  • producing 114.6 thousand barrels oil equivalent per day (MBOEPD), up 1% from the second quarter of 2010, primarily reflecting continued production growth in the Spraberry field,
  • ramping up Spraberry drilling as planned; currently running 25 rigs and expect to be at 30 rigs by year-end 2010,
  • drilling deeper to the Lower Wolfcamp and Strawn intervals in the Spraberry field, with production results exceeding expectations,
  • ramping up Eagle Ford Shale drilling as planned; currently running seven rigs,
  • continuing to deliver strong initial production rates from recently drilled wells in the Eagle Ford Shale,
  • executing third-party gas processing, fractionation and transportation agreement for Eagle Ford Shale gas and oil production with Enterprise Product Partners L.P.,
  • drilling three successful operated wells in Tunisia, with two additional wells currently drilling and
  • adding attractive oil derivative positions for 2012 and 2013.
Scott Sheffield, Chairman and CEO, stated, "We are executing on our plan to significantly ramp-up drilling in the Spraberry field and the Eagle Ford Shale and to vertically integrate in both fields. As a result, we continue to expect the Company to deliver compound annual production growth of 15+% over the 2011 through 2013 period. Cash flow is forecasted to substantially increase from $1.2 billion in 2010 to $2.0 billion in 2013, assuming current NYMEX strip prices and taking into account the Company's attractive oil and gas derivatives position. We remain committed to spending within cash flow and maintaining our strong financial position."

Operations Update

In the Spraberry field in West Texas, Pioneer's drilling ramp-up continues to be on schedule, with 25 rigs currently operating. The Company expects to drill approximately 440 wells during 2010 and anticipates increasing the rig count to 30 rigs by year end and to be at 40 rigs in 2012.

As forecasted, this drilling program is generating quarter-to-quarter Spraberry production growth during 2010. Third quarter production was 35 MBOEPD, up 7% from the second quarter of 2010. The third quarter production level exceeded Pioneer's forecast for the quarter by 1.5 MBOEPD due to better well performance associated with deeper drilling in the field. Production is expected to increase further to approximately 36 MBOEPD during the fourth quarter of 2010, which is 2 MBOEPD more than the Company's prior forecast for the fourth quarter. At this level, Pioneer's fourth quarter 2010 production will be 16% more than the fourth quarter of 2009 and will significantly exceed the Company's prior forecast of 10+% over this period.

The 2010 drilling program is adding incremental production and proved reserves from completions in the Lower Wolfcamp, shale/silt and the deeper Strawn intervals. Initial cumulative five-month production rates from wells drilled to these intervals in 2010 have averaged 30+% higher than the cumulative five-month production rates of a traditional Spraberry/Dean/Upper Wolfcamp well. Pioneer's internal rate of return on its 2010 Spraberry drilling program has been approximately 50% before tax based on current NYMEX strip commodity prices and estimated future production costs.

The Company has commenced a two-well program to test horizontal drilling in the Wolfcamp interval. Both wells are expected to be completed by the end of the year. Water injection was initiated in August on the Company's 7,000-acre waterflood project, with first oil response expected during the first half of 2011.

Based on the planned ramp-up schedule to 40 drilling rigs in 2012 and the incremental production being generated from drilling to deeper intervals, Spraberry field production is expected to at least double from 2010 to 2013, reflecting a compounded annual production growth rate of more than 25%.

As Pioneer ramps up Spraberry field activity, the Company continues to focus on controlling drilling and production costs. The Company is expanding its integrated services in the Spraberry field and plans to internally provide 30% to 60% of its service requirements by 2012. A second Company-owned fracture stimulation fleet has recently commenced operating in the field. Two additional fleets are being built, with one being delivered in the first quarter of 2011 and the second in the second quarter of 2011. To support its fracture stimulation operations, Pioneer has contracts in place for its forecasted sand needs through 2015. Frac tank ownership will more than double from 250 tanks currently to 550 tanks by year end. Tubular requirements have been contracted through 2012, and pumping unit requirements have been contracted through 2011. In addition, the Company has nine owned drilling rigs currently operating and has recently acquired three additional rigs that will be operational by year end. Four pulling units are being added, which will bring the total fleet to 23 units by mid-2011. The Company also has hot oil units, water transport trucks, reverse units and fishing tools to support its growing operations. Vertical integration is expected to save Pioneer $200 thousand to $300 thousand per well compared to utilizing third-party services.

In the highly prospective Eagle Ford Shale in South Texas, Pioneer has successfully drilled and completed 14 horizontal wells. Six of the wells are on production, including one which began flowing to sales this month after the startup of Pioneer's first central gathering plant which provides gas processing and condensate stabilization. The remaining eight wells are expected to be brought online by mid-January following the completion of four additional central gathering plants. Eight additional wells are awaiting completion and will also be brought online as the four central gathering plants are completed.

The Company's drilling program in the Eagle Ford Shale has continued to deliver strong initial production rates. Average initial production rates for the eight wells drilled during the June through October period averaged 2 MBOEPD on 24-hour restricted flow tests with an average condensate yield of 120 barrels per million cubic feet, a liquids yield of 55% and an average heat content of 1,220 British thermal units per cubic foot. The average flowing tubing pressure on these wells was 6,200 pounds per square inch.

Pioneer now has seven rigs running in the play as planned. Along with the drilling ramp up, drilling efficiency improvements are also being achieved, with drilling times having been reduced by 20% since inception. Pioneer and its joint venture partners have agreed to a joint venture development plan which will allow the joint venture to maintain its substantial acreage position. Plans currently call for drilling 70 wells in 2011, 120 wells in 2012 and 140 wells in 2013.

To support the drilling program, Pioneer is purchasing a fracture stimulation fleet that is expected to be in service by the second quarter of 2011 and has entered into a two-year contract for third-party fracture stimulation services beginning in the first quarter of 2011. The Company has also executed an agreement with Enterprise Products Partners L.P. to process, fractionate and transport gas and oil production.

Based on the joint venture development plan, Pioneer expects to exit 2010 in the Eagle Ford Shale at a net production rate of approximately 5 MBOEPD. Average annual production in 2011 is expected to grow to a range of 10 MBOEPD to 13 MBOEPD with a further increase to a range of 32 MBOEPD to 41 MBOEPD in 2013.

Pioneer continues to acquire acreage in the liquids-rich Barnett Shale Combo Play, where the Company has more than 48,000 net acres under lease, representing approximately 500 drilling locations. The Company has commenced drilling in the play with one rig. The Company has acquired 70 square miles of 3-D seismic covering its acreage and expects to increase this coverage to 150 square miles by year end. Assuming current NYMEX strip commodity prices, a drilling cost of $2.8 million and a gross estimated ultimate recovery (EUR) of 320 thousand barrels oil equivalent (BOE), Pioneer's internal rate of return in the Barnett Shale Combo Play is expected to be approximately 45% before tax. The Company is also participating in six non-operated wells in the Barnett Shale during 2010.

On the North Slope of Alaska, Pioneer drilled one Nuiqsut well during the third quarter to test the production capability of a dual lateral. The well tested at a rate of 1,900 barrels oil per day (MBOPD) and is now producing to sales. Pioneer plans to drill two additional Nuiqsut dual lateral wells and one Kuparuk well during the fourth quarter. Further testing of the Moraine zone will begin during the first quarter of 2011. Production in Alaska was 7 MBOPD during the third quarter, essentially flat compared to the second quarter, as unplanned maintenance and outages on the Trans Alaska Pipeline offset production increases from new wells.

In the Mid-Continent area (Panhandle of Texas and western Kansas), third quarter 2010 production was 21 MBOEPD, essentially flat compared to the second quarter of 2010. In the Raton Basin (southeastern Colorado) and the Edwards Trend (South Texas), where gas drilling has been curtailed since the beginning of 2009 due to low gas prices, third quarter 2010 production was 169 million cubic feet per day (MMCFPD) and 51 MMCFPD, respectively. These rates were essentially flat with production in the second quarter of 2010.

In Tunisia, production for the third quarter was 5 MBOEPD, essentially the same as the second quarter. During the second and third quarters, Pioneer drilled three successful operated wells identified from new 3-D seismic reprocessing in its Cherouq and Anaguid concessions. The wells tested at a combined gross production rate of 10 MBOEPD. Production from all three wells is expected to be flowing to sales in early 2011. Based on the successful results of these three wells, Pioneer will drill two additional appraisal wells during the fourth quarter. Pioneer anticipates that after drilling and completing these two wells, the Company's net production from Tunisia will be in the range of 8 MBOEPD to 9 MBOEPD by early 2011.

In South Africa, third quarter production was 5.6 MBOEPD, essentially flat with the second quarter of 2010.

2010 Capital Expenditures

Pioneer's capital program for 2010 (including midstream investments) continues to be forecasted to total $1.2 billion. Drilling capital (excluding asset retirement obligations, capitalized interest and G&G G&A) is forecast at $960 million and is focused on oil drilling. This includes 440 Spraberry wells ($580 million), 35 wells in the Eagle Ford Shale ($100 million, including the benefit of the drilling carry paid or to be paid by Reliance in accordance with the joint venture agreement), one rig in Alaska ($120 million), eight wells in Tunisia ($65 million, including five operated and three non-operated wells), one rig in the liquids-rich areas of the Barnett Shale Combo Play and other drilling-related activities across Pioneer's other assets ($45 million). Land capital is forecasted at $150 million to add acreage in the Eagle Ford Shale, the liquids-rich areas of the Barnett Shale and the Spraberry field. Another $50 million will be spent on midstream facility development activity in the Eagle Ford Shale. Dry gas drilling continues to be curtailed.

Operating cash flow to fund this capital spending is forecasted to be $1.2 billion, assuming current NYMEX strip commodity prices and including the receipt earlier this year of a refund of past royalty overpayments plus interest totaling $155 million from the Minerals Management Service (now the Bureau of Ocean Energy Management, Regulation and Enforcement). The operating cash flow of $1.2 billion excludes the upfront cash payment of $266 million received from Reliance related to the Eagle Ford Shale joint venture transaction.

Third Quarter 2010 Financial Review

Third quarter sales from continuing operations averaged 114.6 MBOEPD, consisting of oil sales averaging 33.7 MBOPD, natural gas liquids (NGL) sales averaging 20.5 thousand barrels per day and gas sales averaging 362 MMCFPD.

The average reported third quarter price for oil was $84.71 per barrel and included $7.31 per barrel related to deferred revenue from volumetric production payments (VPPs) for which production was not recorded. The average reported price for NGLs was $34.46 per barrel. The average reported price for gas was $4.31 per thousand cubic feet.

Third quarter production costs averaged $13.03 per BOE and were higher than the second quarter of 2010 by $1.15 per BOE. This increase was primarily due to production tax refunds received in the second quarter and more workover activities during the third quarter.

Depreciation, depletion and amortization (DD&A) expense averaged $14.50 per BOE for the third quarter. Exploration and abandonment costs were $23 million for the quarter and included $9 million of acreage abandonments and $14 million of geologic and geophysical expenses and personnel costs.

Cash flow from operating activities for the third quarter was $209 million.

Fourth Quarter 2010 Financial Outlook

The following paragraphs provide the Company's fourth quarter of 2010 outlook for certain operating and financial items.

Production is forecasted to average 115 MBOEPD to 120 MBOEPD, reflecting planned drilling activity and the oil lifting schedule for Tunisia.

Production costs are expected to average $11.75 to $13.75 per BOE, based on current NYMEX strip commodity prices. DD&A expense is expected to average $14.25 to $15.50 per BOE.

Total exploration and abandonment expense is forecasted to be $35 million to $45 million, primarily related to exploration wells, including related acreage costs, and seismic and personnel costs.

General and administrative expense is expected to be $43 million to $47 million, interest expense is expected to be $44 million to $47 million, and other expense is expected to be $15 million to $20 million. Accretion of discount on asset retirement obligations is expected to be $2 million to $4 million.

Noncontrolling interest in consolidated subsidiaries' income, excluding unrealized mark-to-market adjustments, is expected to be $9 million to $12 million, primarily reflecting the public ownership in Pioneer Southwest Energy Partners L.P.

The Company's effective income tax rate is expected to range from 40% to 50% based on current capital spending plans, higher tax rates in Tunisia and the assumption of no significant unrealized mark-to-market changes in the Company's derivative position. Cash taxes are expected to be $15 million to $25 million and are primarily attributable to Tunisia and South Africa.

The Company's financial and mark-to-market results, derivatives for oil, NGL and gas, amortization of net deferred gains on discontinued/terminated commodity hedges and future VPP amortization are outlined on the attached schedules.

Earnings Conference Call

On October 27, 2010, at 9:00 a.m. Central Time, Pioneer will discuss its financial and operating results for the quarter ended September 30, 2010, with an accompanying presentation. Instructions for listening to the call and viewing the accompanying presentation are shown below.

Internet: www.pxd.com

Select "Investors," then "Earnings Calls & Webcasts" to listen to the discussion and view the presentation. Telephone: Dial (888) 554-1429 confirmation code: 4755364 five minutes before the call. View the presentation via Pioneer's internet address above. A replay of the webcast will be archived on Pioneer's website. A telephone replay will be available through November 17 by dialing (888) 203-1112 confirmation code: 4755364.

Pioneer is a large independent oil and gas exploration and production company, headquartered in Dallas, Texas, with operations primarily in the United States. For more information, visit Pioneer's website at www.pxd.com.

Except for historical information contained herein, the statements in this news release are forward-looking statements that are made pursuant to the Safe Harbor Provisions of the Private Securities Litigation Reform Act of 1995. Forward-looking statements and the business prospects of Pioneer are subject to a number of risks and uncertainties that may cause Pioneer's actual results in future periods to differ materially from the forward-looking statements. These risks and uncertainties include, among other things, volatility of commodity prices, product supply and demand, competition, the ability to obtain environmental and other permits and the timing thereof, other government regulation or action, the ability to obtain approvals from third parties and negotiate agreements with third parties on mutually acceptable terms, international operations and associated international political and economic instability, litigation, the costs and results of drilling and operations, availability of equipment, services and personnel required to complete the Company's operating activities, access to and availability of transportation, processing and refining facilities, Pioneer's ability to replace reserves, implement its business plans or complete its development activities as scheduled, access to and cost of capital, the financial strength of counterparties to Pioneer's credit facility and derivative contracts and the purchasers of Pioneer's oil, NGL and gas production, uncertainties about estimates of reserves and resource potential and the ability to add proved reserves in the future, the assumptions underlying production forecasts, quality of technical data, environmental and weather risks, including the possible impacts of climate change, and acts of war or terrorism. Sensitivity price cases for proved reserves mentioned in this presentation may not be attained or sustained. These and other risks are described in Pioneer's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission. In addition, Pioneer may be subject to currently unforeseen risks that may have a materially adverse impact on it. Pioneer undertakes no duty to publicly update these statements except as required by law.

Cautionary Note to U.S. Investors --The U.S. Securities and Exchange Commission (the "SEC") prohibits oil and gas companies, in their filings with the SEC, from disclosing estimates of oil or gas resources other than "reserves," as that term is defined by the SEC. In this presentation, Pioneer includes estimates of quantities of oil and gas using certain terms, such as "resource potential," "EUR" or other descriptions of volumes of reserves, which terms include quantities of oil and gas that may not meet the SEC's definitions of proved, probable and possible reserves, and which the SEC's guidelines strictly prohibit Pioneer from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being recovered by Pioneer. U.S. investors are urged to consider closely the disclosures in the Company's periodic filings with the SEC. Such filings are available from the Company at 5205 N. O'Connor Blvd., Suite 200, Irving, Texas 75039, Attention: Investor Relations, and the Company's website at www.pxd.com. These filings also can be obtained from the SEC by calling 1-800-SEC-0330.

PIONEER NATURAL RESOURCES COMPANY UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (in thousands)
September 30, December 31,

2010
2009 ASSETS Current assets:





Cash and cash equivalents
$ 78,165

$ 27,368
Accounts receivable, net

211,716


331,748
Income taxes receivable

8,333


25,022
Inventories

182,238


139,177
Prepaid expenses

17,868


9,011
Deferred income taxes

-


26,857
Derivatives

189,635


48,713
Other current assets, net
1,521
8,222





Total current assets
689,476
616,118





Property, plant and equipment, at cost:





Oil and gas properties, using the successful efforts method of accounting

10,979,208


10,512,904
Accumulated depletion, depreciation and amortization
(3,312,709 )
(2,946,048 )





Total property, plant and equipment
7,666,499
7,566,856





Deferred income taxes

15,045


387
Goodwill

298,413


309,259
Derivatives

210,823


43,631
Other assets, net
416,864
331,014







$ 9,297,120
$ 8,867,265





LIABILITIES AND STOCKHOLDERS' EQUITY Current liabilities:





Accounts payable
$ 363,794

$ 253,583
Interest payable

33,798


47,009
Income taxes payable

18,718


17,411
Deferred income taxes

52,043


128
Deferred revenue

56,097


90,215
Derivatives

34,730


116,015
Other current liabilities
37,041
46,830





Total current liabilities
596,221
571,191





Long-term debt

2,539,416


2,761,011
Deferred income taxes

1,694,575


1,470,899
Deferred revenue

53,400


87,021
Derivatives

31,477


133,645
Other liabilities

224,193


200,467
Stockholders' equity
4,157,838
3,643,031







$ 9,297,120
$ 8,867,265 PIONEER NATURAL RESOURCES COMPANY UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (in thousands, except per share data)
Three Months Ended Nine Months Ended

September 30,
September 30,

2010 2009
2010 2009 Revenues and other income:











Oil and gas
$ 471,372

$ 409,969

$ 1,441,310

$ 1,148,512
Interest and other

11,864


503


51,930


99,761
Derivative gains (losses), net

127,581


(15,222 )

570,585


(85,583 ) Gain (loss) on disposition of assets, net

2,383


(385 )

26,971


(447 ) Hurricane activity, net
3,452
(1,830 )
5,678
(18,280 )

616,652
393,035
2,096,474
1,143,963 Costs and expenses:











Oil and gas production

104,339


90,394


291,348


285,617
Production and ad valorem taxes

33,045


28,089


85,444


79,503
Depletion, depreciation and amortization

152,838


162,605


453,920


509,422
Impairment of oil and gas properties

-


-


-


21,091
Exploration and abandonments

22,963


25,073


70,883


77,861
General and administrative

44,759


34,799


128,081


102,728
Accretion of discount on asset retirement obligations

2,626


2,754


8,218


8,259
Interest

45,002


43,438


137,893


128,051
Other
20,927
21,363
52,228
89,467

426,499
408,515
1,228,015
1,301,999











Income (loss) from continuing operations before income taxes

190,153


(15,480 )

868,459


(158,036 ) Income tax benefit (provision)
(76,661 )
5,206
(331,828 )
47,671 Income (loss) from continuing operations

113,492


(10,274 )

536,631


(110,365 ) Income from discontinued operations, net of tax
1,082
12,107
27,238
13,868 Net income (loss)

114,574


1,833


563,869


(96,497 ) Net income attributable to the noncontrolling interests
(2,538 )
(8,998 )
(39,003 )
(12,269 ) Net income (loss) attributable to common stockholders
$ 112,036
$ (7,165 )
$ 524,866
$ (108,766 )











Basic earnings per share:











Income (loss) from continuing operations attributable to common stockholders
$ 0.94

$ (0.17 )
$ 4.23

$ (1.07 ) Income from discontinued operations attributable to common stockholders
0.01
0.11
0.23
0.12 Net income (loss) attributable to common stockholders
$ 0.95
$ (0.06 )
$ 4.46
$ (0.95 )











Diluted earnings per share:











Income (loss) from continuing operations attributable to common stockholders
$ 0.93

$ (0.17 )
$ 4.20

$ (1.07 ) Income from discontinued operations attributable to common stockholders
0.01
0.11
0.23
0.12 Net income (loss) attributable to common stockholders
$ 0.94
$ (0.06 )
$ 4.43
$ (0.95 )











Weighted average shares outstanding:











Basic
115,191
114,123
114,985
114,118 Diluted
116,021
114,123
115,832
114,118 PIONEER NATURAL RESOURCES COMPANY UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands)
Three Months Ended Nine Months Ended

September 30,
September 30,

2010 2009
2010 2009 Cash flows from operating activities:











Net income (loss)
$ 114,574

$ 1,833

$ 563,869

$ (96,497 ) Adjustments to reconcile net income (loss) to net cash provided by











operating activities:











Depletion, depreciation and amortization

152,838


162,605


453,920


509,422
Impairment of oil and gas properties

-


-


-


21,091
Exploration expenses, including dry holes

8,714


12,745


16,771


40,699
Hurricane activity, net

-


1,200


3,500


16,200
Deferred income taxes

57,251


(17,456 )

300,303


(67,397 ) (Gain) loss on disposition of assets, net

(2,383 )

385


(26,971 )

447
Accretion of discount on asset retirement obligations

2,626


2,754


8,218


8,259
Discontinued operations

(2,594 )

(10,581

)

8,626


(5,373 ) Interest expense

7,647


7,165




22,567


20,694
Derivative related activity

(107,300 )

70


(549,387 )

48,305
Amortization of stock-based compensation

9,582


10,096


28,631


29,319
Amortization of deferred revenue

(22,669 )

(37,206 )

(67,739 )

(110,901 ) Other noncash items

13,386


5,824


9,620


30,664
Change in operating assets and liabilities











Accounts receivable, net

1,497


17,133


97,873


71,074
Income taxes receivable

(6,751 )

12,966


16,689


44,762
Inventories

(18,938 )

5,620


(6,459 )

(52,069 ) Prepaid expenses

1,229


7,287


(8,975 )

(6,900 ) Other current assets

9,354


31,612


2,162


98,532
Accounts payable

11,891


13,150


62,349


(94,238 ) Interest payable

(20,225 )

(14,867 )

(13,211 )

(14,766 ) Income taxes payable

5,777


(4,790 )

1,307


9,127
Other current liabilities
(6,998 )
(45,048

)
(21,941 )
(89,629 ) Net cash provided by operating activities

208,508


162,497




901,722


410,825
Net cash used in investing activities

(325,829 )

(53,184 )

(564,202 )

(312,991 ) Net cash used in financing activities
(2,200 )
(118,021 )
(286,723 )
(90,556 ) Net increase (decrease) in cash and cash equivalents

(119,521 )

(8,708

)

50,797


7,278
Cash and cash equivalents, beginning of period
197,686
64,323
27,368
48,337 Cash and cash equivalents, end of period
$ 78,165
$ 55,615


$ 78,165
$ 55,615 PIONEER NATURAL RESOURCES COMPANY UNAUDITED SUMMARY PRODUCTION AND PRICE DATA

Three Months Ended Nine Months Ended



September 30,
September 30,



2010 2009
2010 2009 Average Daily Sales Volumes













from Continuing Operations:













Oil (Bbls) -
U.S.

28,880

24,754

27,388

24,989

South Africa

445

575

730

401

Tunisia
4,409
6,334
4,845
6,612

Worldwide
33,734
31,663
32,963
32,002













Natural gas liquids (Bbls) -
U.S.
20,525
18,602
19,649
20,044













Gas (Mcf) -
U.S.

327,917

341,874

335,960

360,896

South Africa

31,069

31,372

30,304

31,637

Tunisia
2,760
904
2,711
1,662

Worldwide
361,746
374,150
368,975
394,195













Total (BOE) -
U.S.

104,058

100,335

103,030

105,182

South Africa

5,623

5,803

5,781

5,674

Tunisia
4,869
6,485
5,297
6,890

Worldwide
114,550
112,623
114,108
117,746













Average Reported Prices (a):













Oil (per Bbl) -
U.S.
$ 86.06
$ 81.57
$ 89.08
$ 70.13

South Africa
$ 77.84
$ 70.30
$ 77.43
$ 63.08

Tunisia
$ 76.54
$ 65.76
$ 76.72
$ 56.83

Worldwide
$ 84.71
$ 78.20
$ 87.00
$ 67.29













Natural gas liquids (per Bbl) -
U.S.
$ 34.46
$ 33.13
$ 36.80
$ 27.33













Gas (per Mcf) -
U.S.
$ 4.06
$ 3.42
$ 4.37
$ 3.69

South Africa
$ 6.34
$ 5.93
$ 6.26
$ 5.08

Tunisia
$ 11.50
$ 9.35
$ 11.27
$ 7.22

Worldwide
$ 4.31
$ 3.64
$ 4.58
$ 3.82



























Total (BOE) -
U.S.
$ 43.46
$ 37.92
$ 44.95
$ 34.54

South Africa
$ 41.17
$ 39.03
$ 42.57
$ 32.80

Tunisia
$ 75.83
$ 65.54
$ 75.94
$ 56.28

Worldwide
$ 44.73
$ 39.57
$ 46.27
$ 35.73 _____________

(a) Average prices are attributable to continuing operations and include the results of hedging activities and amortization of VPP deferred revenue.



PIONEER NATURAL RESOURCES COMPANY
UNAUDITED SUPPLEMENTARY EARNINGS PER SHARE INFORMATION

The Company uses the two-class method of calculating basic and diluted earnings per share. Under the two-class method of calculating earnings per share, GAAP provides that share- and unit-based awards with guaranteed dividend or distribution participation rights qualify as "participating securities" during their vesting periods. The Company's basic net income (loss) per share attributable to common stockholders is computed as (i) net income (loss) attributable to common stockholders, (ii) less participating share- and unit-based basic earnings (iii) divided by weighted average basic shares outstanding. The Company's diluted net income (loss) per share attributable to common stockholders is computed as (i) basic net income (loss) attributable to common stockholders, (ii) plus adjustments to participating undistributed earnings (iii) divided by weighted average diluted shares outstanding. During periods in which the Company realizes a loss from continuing operations attributable to common stockholders, securities or other contracts to issue common stock would not be dilutive to loss per share and conversion into common stock is assumed not to occur.

The following table is a reconciliation of the Company's net income (loss) attributable to common stockholders to basic net income (loss) attributable to common stockholders and to diluted net income (loss) attributable to common stockholders for the three and nine months ended September 30, 2010 and 2009:


Three Months Ended Nine Months Ended

September 30,
September 30,

2010 2009
2010 2009

(in thousands)











Net income (loss) attributable to common stockholders
$ 112,036
$ (7,165)
$ 524,866
$ (108,766) Participating basic distributed earnings

(18)

-

(125)

(94) Participating basic undistributed earnings
(2,672)
-
(11,895)
- Basic net income (loss) attributable to common stockholders

109,346

(7,165)

512,846

(108,860) Diluted adjustments to share- and unit-based earnings
19
-
128
- Diluted net income (loss) attributable to common











stockholders
$ 109,365
$ (7,165)
$ 512,974
$ (108,860)











The following table is a reconciliation of basic weighted average common shares outstanding to diluted weighted average common shares outstanding for the three and nine months ended September 30, 2010 and 2009:


Three Months Ended Nine Months Ended

September 30,
September 30,

2010 2009
2010 2009

(in thousands)







Weighted average common shares outstanding:







Basic
115,191
114,123
114,985
114,118 Dilutive common stock options
168
-
218
- Contingently issuable - performance shares
662
-
629
-







Diluted
116,021
114,123
115,832
114,118















PIONEER NATURAL RESOURCES COMPANY
UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES
(in thousands)

EBITDAX and discretionary cash flow ("DCF") (as defined below) are presented herein, and reconciled to the generally accepted accounting principle ("GAAP") measures of net income (loss) and net cash provided by operating activities because of their wide acceptance by the investment community as financial indicators of a company's ability to internally fund exploration and development activities and to service or incur debt. The Company also views the non-GAAP measures of EBITDAX and DCF as useful tools for comparisons of the Company's financial indicators with those of peer companies that follow the full cost method of accounting. EBITDAX and DCF should not be considered as alternatives to net income (loss) or net cash provided by operating activities, as defined by GAAP.


Three Months Ended Nine Months Ended

September 30,
September 30,

2010 2009
2010 2009











Net income (loss)
$ 114,574

$ 1,833

$ 563,869

$ (96,497 ) Depletion, depreciation and amortization

152,838


162,605


453,920


509,422
Impairment of oil and gas properties

-


-


-


21,091
Exploration and abandonments

22,963


25,073


70,883


77,861
Hurricane activity, net

(3,452 )

1,830


(5,678 )

18,280
Accretion of discount on asset retirement obligations

2,626


2,754


8,218


8,259
Interest expense

45,002


43,438


137,893


128,051
Income tax (benefit) provision

76,661


(5,206 )

331,828


(47,671 ) (Gain) loss on disposition of assets, net

(2,383 )

385


(26,971 )

447
Discontinued operations

(1,082 )

(12,107 )

(27,238 )

(13,868 ) Derivative related activity

(107,300 )

70


(549,387 )

48,305
Amortization of stock-based compensation

9,582


10,096


28,631


29,319
Amortization of deferred revenue

(22,669 )

(37,206 )

(67,739 )

(110,901 ) Other noncash items
13,386
5,824
9,620
30,664











EBITDAX (a)

300,746


199,389


927,849


602,762












Cash interest expense

(37,355 )

(36,273

)

(115,326 )

(107,357 ) Current income taxes
(19,410 )
(12,250 )
(31,525 )
(19,726 )











Discretionary cash flow (b)

243,981


150,866




780,998


475,679












Cash hurricane activity

3,452


(630 )

9,178


(2,080 ) Discontinued operations cash activity

(1,512 )

1,526


35,864


8,495
Cash exploration expense

(14,249 )

(12,328 )

(54,112 )

(37,162 ) Changes in operating assets and liabilities
(23,164 )
23,063
129,794
(34,107 )











Net cash provided by operating activities
$ 208,508
$ 162,497


$ 901,722
$ 410,825 _____________

(a) "EBITDAX" represents earnings before depletion, depreciation and amortization expense; impairment of oil and gas properties; exploration and abandonments; net hurricane activity; unrealized mark-to-market derivative activity; accretion of discount on asset retirement obligations; interest expense; income taxes; (gain) loss on the disposition of assets, net; discontinued operations; amortization of stock-based compensation; amortization of deferred revenue and other noncash items.

(b)
Discretionary cash flow equals cash flows from operating activities before changes in operating assets and liabilities, cash activity reflected in discontinued operations and hurricane activity, and cash exploration expense.



PIONEER NATURAL RESOURCES COMPANY
UNAUDITED SUPPLEMENTARY NON-GAAP FINANCIAL MEASURES (continued)
(in millions, except per share data)

Income adjusted for unrealized mark-to-market derivative gains, and income adjusted for unrealized mark-to-market derivative gains and unusual items, as presented in this press release, are presented and reconciled to Pioneer's net income attributable to common stockholders that is determined in accordance with GAAP because Pioneer believes that these non-GAAP financial measures reflect an additional way of viewing aspects of Pioneer's business that, when viewed together with its financial results computed in accordance with GAAP, provide a more complete understanding of factors and trends affecting its historical financial performance and future operating results, greater transparency of underlying trends and greater comparability of results across periods. In addition, management believes that these non-GAAP measures may enhance investors' ability to assess Pioneer's historical and future financial performance. These non-GAAP financial measures are not intended to be substitutes for the comparable GAAP measures and should be read only in conjunction with Pioneer's consolidated financial statements prepared in accordance with GAAP. Unrealized mark-to-market net derivative gains, impairment of dry gas well pipe inventory, Alaskan Petroleum Production Tax credits, net hurricane related credits and net discontinued operations will recur in future periods; however, the amount and frequency of each item can vary significantly from period to period. The table below reconciles Pioneer's net income attributable to common stockholders for the three months ended September 30, 2010, as determined in accordance with GAAP, to income adjusted for unrealized mark-to-market derivative gains, and income adjusted for unrealized mark-to-market derivative gains and unusual items, for that quarter.



Diluted

After-tax
Amounts

Amounts
Per Share





Net income attributable to common stockholders
$ 112



$ 0.94
Unrealized mark-to-market derivative gains, net ($94 pretax)


(63

)
(0.53 ) Income adjusted for unrealized mark-to-market derivative gains



49




0.41






Impairment of dry gas well pipe inventory ($6 pretax) (a)



4




0.03
Petroleum production tax credit income ($12 pretax)



(8

)

(0.06 ) Hurricane related credits, net ($3 pretax)



(2

)

(0.02 ) Discontinued operations income ($2 pretax)


(1

)
(0.01 ) Income as adjusted for unrealized mark-to-market derivative gains and unusual items


$ 42


$ 0.35 PIONEER NATURAL RESOURCES COMPANY SUPPLEMENTAL INFORMATION Open Commodity Derivative Positions as of October 25, 2010 (Volumes are average daily amounts)
2010











Fourth









Quarter
2011
2012
2013
2014














Oil Derivatives (BBLs):














Swap Contracts:














Volume

2,500


750


3,000


3,000


-
NYMEX price
$ 93.34

$ 77.25

$ 79.32

$ 81.02

$ -
Collar Contracts:














Volume

-


2,000


-


-


-
NYMEX price:














Ceiling
$ -

$ 170.00

$ -

$ -

$ -
Floor
$ -

$ 115.00

$ -

$ -

$ -
Collar Contracts with Short Puts:














Volume

30,250


32,000


37,000


21,250


-
Price (a):














Ceiling
$ 85.09

$ 99.33

$ 118.34

$ 117.38

$ -
Floor
$ 68.38

$ 73.75

$ 80.41

$ 80.18

$ -
Short Put
$ 55.23

$ 59.31

$ 65.00

$ 65.18

$ -
Percent of total oil production (b)

~90

%



~80

%



~85

%



~40

%



N/A
NGL Derivatives (BBLs):














Swap Contracts:














Volume

1,650


750


750


-


-
Blended index price (c)
$ 40.85

$ 34.65

$ 35.03

$ -

$ -
Collar Contracts:














Volume

2,000


1,000


-


-


-
Index price (c):














Ceiling
$ 49.98

$ 50.93

$ -

$ -

$ -
Floor
$ 41.58

$ 42.21

$ -

$ -

$ -
Collar Contracts with Short Puts:














Volume

2,000


-


-


-


-
Index price (c):














Ceiling
$ 58.92

$ -

$ -

$ -

$ -
Floor
$ 47.64

$ -

$ -

$ -

$ -
Short Put
$ 38.71

$ -

$ -

$ -

$ -
Percent of total NGL production (b)

~25

%



~5

%



<5

%



N/A


N/A
Gas Derivatives (MMBtu):














Swap Contracts:














Volume

167,500


117,500


105,000


67,500


50,000
NYMEX price (d)
$ 6.26

$ 6.13

$ 5.82

$ 6.11

$ 6.05
Collar Contracts:














Volume

40,000


-


65,000


100,000


20,000
NYMEX price (d):














Ceiling
$ 7.19

$ -

$ 6.60

$ 6.50

$ 7.20
Floor
$ 5.75

$ -

$ 5.00

$ 5.00

$ 5.00
Collar Contracts with Short Puts:














Volume

95,000


200,000


190,000


45,000


50,000
NYMEX price (d):














Ceiling
$ 7.94

$ 8.55

$ 7.96

$ 7.49

$ 8.08
Floor
$ 6.00

$ 6.32

$ 6.12

$ 6.00

$ 6.00
Short Put
$ 5.00

$ 4.88

$ 4.55

$ 4.50

$ 4.50
Percent of total U.S. gas production (b)



~90

%



~90

%



~85

%



~45

%



~25

%

Basis Swap Contracts:














Permian Basin Index Swaps volume - (e)

20,054


10,000


32,500


2,500


-
Price differential ($/MMBtu)
$ (0.33 )
$ (0.31 )
$ (0.38 )
$ (0.31 )
$ -
Mid-Continent Index Swaps volume - (e)

183,370


100,000


40,000


10,000


-
Price differential ($/MMBtu)
$ (0.84 )
$ (0.71 )
$ (0.58 )
$ (0.71 )
$ -
Gulf Coast Index Swaps volume - (e)

41,685


23,500


43,500


20,000


10,000
Price differential ($/MMBtu)
$ (0.22 )
$ (0.16 )
$ (0.16 )
$ (0.16 )
$ (0.16 ) _____________

(a) Represents NYMEX and Dated Brent average prices of U.S. and foreign production. (b)
Represents an estimated percentage of forecasted production, which may differ from the percentage of actual production. (c)
Represents the blended Mont Belvieu index price or respective NGL component prices per Bbl. (d)
Represents the NYMEX Henry Hub index price or approximate NYMEX Henry Hub index price based on historical differentials to the index price on the derivative trade date. (e)
Represent swaps that fix the basis differentials between indices at which the Company sells its Permian Basin, Mid-Continent and Gulf Coast gas and NYMEX Henry Hub index prices. PIONEER NATURAL RESOURCES COMPANY SUPPLEMENTAL INFORMATION Amortization of Deferred Revenue Associated with Volumetric Production Payments and Net Derivative Losses as of September 30, 2010 (in thousands)
2010







Fourth







Quarter
2011
2012
Total











Total deferred revenues (a)
$ 22,475

$ 44,951

$ 42,071

$ 109,497
Less derivative losses to be recognized in











pretax earnings (b)
(538 )
(3,571 )
(3,159 )
(7,268 )











Total VPP impact to pretax earnings
$ 21,937
$ 41,380
$ 38,912
$ 102,229 _____________

(a) Deferred revenue will be amortized as increases to oil and gas revenues during the indicated future periods. (b)
Represents the remaining pretax earnings impact of the derivatives assigned in the VPPs.

Deferred Gains on Discontinued and Terminated Commodity Hedges as of September 30, 2010 (a)
(in thousands)


2010



Fourth



Quarter
2011









Commodity hedge gains (b):





Oil
$ 19,178
$ 36,489 NGL

1,840

- Gas
931
-

$ 21,949
$ 36,489 _____________

(a) Excludes deferred hedge gains and losses on terminated derivatives related to the VPPs. (b)
Deferred commodity hedge gains will be amortized as increases to oil and gas revenues during the indicated future periods. PIONEER NATURAL RESOURCES COMPANY SUPPLEMENTAL INFORMATION Derivative Gains, Net (in thousands)
Three Months Nine Months

Ended
Ended

September 30, 2010


September 30, 2010

Unrealized mark-to-market changes in fair value:







Oil derivative gains (losses)
$ (64,788 )
$ 120,808
NGL derivative gains (losses)

(7,130 )

14,073
Gas derivative gains

151,770


324,608
Interest rate derivative gains
13,881
47,419 Total unrealized mark-to-market derivative gains, net (a)


93,733
506,908





Cash settled changes in fair value:





Oil derivative losses

(360 )

(12,428 ) NGL derivative losses

(565 )

(4,417 ) Gas derivative gains

33,806


77,842
Interest rate derivative gains
967
2,680 Total cash derivative gains, net
33,848
63,677 Total derivative gains, net
$ 127,581
$ 570,585 _____________

(a) Total unrealized mark-to-market derivative gains, net includes $6.4 million of losses and $12.1 million of gains attributable to noncontrolling interests in consolidated subsidiaries during the three and nine month periods ending September 30, 2010, respectively.

Add your comment:
Advertisement
Advertisement
Advertisement
Advertisement
Advertisement