ý | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
Delaware | 75-2702753 | |
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |
5205 N. O'Connor Blvd., Suite 200, Irving, Texas | 75039 | |
(Address of principal executive offices) | (Zip Code) |
Large accelerated filer | ý | Accelerated filer | ¨ | |||
Non-accelerated filer | o (Do not check if a smaller reporting company) | Smaller reporting company | ¨ |
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Item 3. | ||
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Item 1A. | ||
Item 2. | ||
Item 4. | ||
Item 6. | ||
• | "BBL" means a standard barrel containing 42 United States gallons. |
• | "BOE" means a barrel of oil equivalent and is a standard convention used to express oil and gas volumes on a comparable oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of six thousand cubic feet of gas to one BBL of oil or natural gas liquid. |
• | "BOEPD" means BOE per day. |
• | "BTU" means British thermal unit, which is a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit. |
• | "Conway" means the daily average natural gas liquids components as priced in Oil Price Information Service ("OPIS") in the table "U.S. and Canada LP – Gas Weekly Averages" at Conway, Kansas. |
• | "DD&A" means depletion, depreciation and amortization. |
• | "GAAP" means accounting principles that are generally accepted in the United States of America. |
• | "LIBOR" means London Interbank Offered Rate, which is a market rate of interest. |
• | "MCF" means one thousand cubic feet and is a measure of gas volume. |
• | "MMBTU" means one million BTUs. |
• | "MMBTUPD" means MMBTU per day. |
• | "Mont Belvieu" means the daily average natural gas liquids components as priced in OPIS in the table "U.S. and Canada LP – Gas Weekly Averages" at Mont Belvieu, Texas. |
• | "NGL" means natural gas liquid. |
• | "NYMEX" means the New York Mercantile Exchange. |
• | "Pioneer" or the "Company" means Pioneer Natural Resources Company and its subsidiaries. |
• | "Pioneer Southwest" means Pioneer Southwest Energy Partners L.P. and its subsidiaries. |
• | "Proved reserves" mean the quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations – prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time. |
• | "U.S." means United States. |
• | With respect to information on the working interest in wells, drilling locations and acreage, "net" wells, drilling locations and acres are determined by multiplying "gross" wells, drilling locations and acres by the Company's working interest in such wells, drilling locations or acres. Unless otherwise specified, wells, drilling locations and acreage statistics quoted herein represent gross wells, drilling locations or acres. |
• | Unless otherwise indicated, all currency amounts are expressed in U.S. dollars. |
September 30, 2012 | December 31, 2011 | |||||||
(Unaudited) | ||||||||
ASSETS | ||||||||
Current assets: | ||||||||
Cash and cash equivalents | $ | 333,886 | $ | 537,484 | ||||
Accounts receivable: | ||||||||
Trade, net of allowance for doubtful accounts of $832 and $806 as of September 30, 2012 and December 31, 2011, respectively | 298,320 | 275,991 | ||||||
Due from affiliates | 2,250 | 7,822 | ||||||
Income taxes receivable | 10,126 | 3 | ||||||
Inventories | 277,419 | 241,609 | ||||||
Prepaid expenses | 21,657 | 14,263 | ||||||
Discontinued operations held for sale | 400,392 | 73,349 | ||||||
Other current assets: | ||||||||
Derivatives | 225,900 | 238,835 | ||||||
Other | 9,934 | 12,936 | ||||||
Total current assets | 1,579,884 | 1,402,292 | ||||||
Property, plant and equipment, at cost: | ||||||||
Oil and gas properties, using the successful efforts method of accounting: | ||||||||
Proved properties | 13,250,249 | 12,013,805 | ||||||
Unproved properties | 203,285 | 235,527 | ||||||
Accumulated depletion, depreciation and amortization | (4,107,432 | ) | (3,648,465 | ) | ||||
Total property, plant and equipment | 9,346,102 | 8,600,867 | ||||||
Goodwill | 293,449 | 298,142 | ||||||
Other property and equipment, net | 1,186,131 | 573,075 | ||||||
Other assets: | ||||||||
Investment in unconsolidated affiliate | 194,003 | 169,532 | ||||||
Derivatives | 101,023 | 243,240 | ||||||
Other, net of allowance for doubtful accounts of $644 and $340 as of September 30, 2012 and December 31, 2011, respectively | 113,409 | 160,008 | ||||||
$ | 12,814,001 | $ | 11,447,156 |
September 30, 2012 | December 31, 2011 | |||||||
(Unaudited) | ||||||||
LIABILITIES AND EQUITY | ||||||||
Current liabilities: | ||||||||
Accounts payable: | ||||||||
Trade | $ | 736,381 | $ | 647,455 | ||||
Due to affiliates | 68,255 | 68,756 | ||||||
Interest payable | 40,960 | 57,240 | ||||||
Income taxes payable | 222 | 9,788 | ||||||
Deferred income taxes | 63,927 | 57,713 | ||||||
Discontinued operations held for sale | 5,919 | 75,901 | ||||||
Other current liabilities: | ||||||||
Derivatives | 14,815 | 74,415 | ||||||
Deferred revenue | 10,575 | 42,069 | ||||||
Other | 50,794 | 36,174 | ||||||
Total current liabilities | 991,848 | 1,069,511 | ||||||
Long-term debt | 3,562,070 | 2,528,905 | ||||||
Derivatives | 27,938 | 33,561 | ||||||
Deferred income taxes | 2,209,472 | 1,942,446 | ||||||
Other liabilities | 222,564 | 221,595 | ||||||
Equity: | ||||||||
Common stock, $.01 par value; 500,000,000 shares authorized; 134,782,883 and 133,121,092 shares issued at September 30, 2012 and December 31, 2011, respectively | 1,348 | 1,331 | ||||||
Additional paid-in capital | 3,641,248 | 3,613,808 | ||||||
Treasury stock at cost: 11,551,195 and 11,264,936 at September 30, 2012 and December 31, 2011, respectively | (504,140 | ) | (458,281 | ) | ||||
Retained earnings | 2,485,935 | 2,335,066 | ||||||
Accumulated other comprehensive loss - net deferred hedge losses, net of tax | — | (3,130 | ) | |||||
Total equity attributable to common stockholders | 5,624,391 | 5,488,794 | ||||||
Noncontrolling interests in consolidating subsidiaries | 175,718 | 162,344 | ||||||
Total equity | 5,800,109 | 5,651,138 | ||||||
Commitments and contingencies | ||||||||
$ | 12,814,001 | $ | 11,447,156 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Revenues and other income: | ||||||||||||||||
Oil and gas | $ | 695,422 | $ | 574,114 | $ | 2,014,920 | $ | 1,595,563 | ||||||||
Interest and other | 18,733 | 7,311 | 53,224 | 49,378 | ||||||||||||
Derivative gains (losses), net | (123,994 | ) | 401,072 | 243,568 | 386,118 | |||||||||||
Gain (loss) on disposition of assets, net | 13,237 | 1,048 | 57,973 | (1,439 | ) | |||||||||||
603,398 | 983,545 | 2,369,685 | 2,029,620 | |||||||||||||
Costs and expenses: | ||||||||||||||||
Oil and gas production | 176,711 | 112,661 | 449,861 | 305,098 | ||||||||||||
Production and ad valorem taxes | 49,036 | 37,713 | 137,797 | 105,982 | ||||||||||||
Depletion, depreciation and amortization | 204,264 | 138,413 | 557,064 | 387,320 | ||||||||||||
Exploration and abandonments | 26,652 | 14,021 | 108,914 | 42,809 | ||||||||||||
General and administrative | 62,567 | 49,618 | 180,591 | 137,868 | ||||||||||||
Accretion of discount on asset retirement obligations | 2,369 | 1,993 | 6,994 | 5,930 | ||||||||||||
Interest | 54,441 | 45,560 | 150,307 | 135,782 | ||||||||||||
Hurricane activity, net | — | (1,487 | ) | — | (1,418 | ) | ||||||||||
Other | 31,923 | 17,057 | 86,028 | 46,971 | ||||||||||||
607,963 | 415,549 | 1,677,556 | 1,166,342 | |||||||||||||
Income (loss) from continuing operations before income taxes | (4,565 | ) | 567,996 | 692,129 | 863,278 | |||||||||||
Income tax provision | (8,386 | ) | (182,728 | ) | (248,535 | ) | (278,732 | ) | ||||||||
Income (loss) from continuing operations | (12,951 | ) | 385,268 | 443,594 | 584,546 | |||||||||||
Income (loss) from discontinued operations, net of tax | 34,650 | 330 | (240,474 | ) | 410,556 | |||||||||||
Net income | 21,699 | 385,598 | 203,120 | 995,102 | ||||||||||||
Net income attributable to noncontrolling interests | (2,475 | ) | (34,134 | ) | (39,669 | ) | (49,467 | ) | ||||||||
Net income attributable to common stockholders | $ | 19,224 | $ | 351,464 | $ | 163,451 | $ | 945,635 | ||||||||
Basic earnings per share: | ||||||||||||||||
Income (loss) from continuing operations attributable to common stockholders | $ | (0.13 | ) | $ | 2.96 | $ | 3.27 | $ | 4.53 | |||||||
Income (loss) from discontinued operations attributable to common stockholders | 0.28 | — | (1.96 | ) | 3.47 | |||||||||||
Net income attributable to common stockholders | $ | 0.15 | $ | 2.96 | $ | 1.31 | $ | 8.00 | ||||||||
Diluted earnings per share: | ||||||||||||||||
Income (loss) from continuing operations attributable to common stockholders | $ | (0.13 | ) | $ | 2.95 | $ | 3.19 | $ | 4.44 | |||||||
Income (loss) from discontinued operations attributable to common stockholders | 0.28 | — | (1.91 | ) | 3.41 | |||||||||||
Net income attributable to common stockholders | $ | 0.15 | $ | 2.95 | $ | 1.28 | $ | 7.85 | ||||||||
Weighted average shares outstanding: | ||||||||||||||||
Basic | 123,111 | 116,281 | 122,874 | 116,122 | ||||||||||||
Diluted | 123,111 | 117,075 | 126,111 | 118,350 | ||||||||||||
Dividends declared per share | $ | 0.04 | $ | 0.04 | $ | 0.08 | $ | 0.08 | ||||||||
Amounts attributable to common stockholders: | ||||||||||||||||
Income (loss) from continuing operations | $ | (15,426 | ) | $ | 351,134 | $ | 403,925 | $ | 535,079 | |||||||
Income (loss) from discontinued operations, net of tax | 34,650 | 330 | (240,474 | ) | 410,556 | |||||||||||
Net income | $ | 19,224 | $ | 351,464 | $ | 163,451 | $ | 945,635 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Net income | $ | 21,699 | $ | 385,598 | $ | 203,120 | $ | 995,102 | ||||||||
Other comprehensive activity: | ||||||||||||||||
Net hedge (gains) losses included in continuing operations | — | (8,224 | ) | 4,855 | (24,418 | ) | ||||||||||
Income tax (benefit) provision | — | 1,838 | (1,725 | ) | 6,724 | |||||||||||
Other comprehensive activity | — | (6,386 | ) | 3,130 | (17,694 | ) | ||||||||||
Comprehensive income | 21,699 | 379,212 | 206,250 | 977,408 | ||||||||||||
Comprehensive income attributable to the noncontrolling interests | (2,475 | ) | (30,670 | ) | (39,669 | ) | (39,192 | ) | ||||||||
Comprehensive income attributable to common stockholders | $ | 19,224 | $ | 348,542 | $ | 166,581 | $ | 938,216 |
Equity Attributable To Common Stockholders | |||||||||||||||||||||||||||||||
Shares Outstanding | Common Stock | Additional Paid-in Capital | Treasury Stock | Retained Earnings | Accumulated Other Comprehensive Loss | Noncontrolling Interests | Total Equity | ||||||||||||||||||||||||
Balance as of December 31, 2011 | 121,856 | $ | 1,331 | $ | 3,613,808 | $ | (458,281 | ) | $ | 2,335,066 | $ | (3,130 | ) | $ | 162,344 | $ | 5,651,138 | ||||||||||||||
Dividends declared ($0.08 per share) | — | — | — | — | (9,999 | ) | — | — | (9,999 | ) | |||||||||||||||||||||
Exercise of long-term incentive plan stock options and employee stock purchases | 190 | — | (969 | ) | 10,624 | (2,583 | ) | — | — | 7,072 | |||||||||||||||||||||
Treasury stock purchases | (477 | ) | — | — | (56,488 | ) | — | — | (189 | ) | (56,677 | ) | |||||||||||||||||||
Conversion of 2.875% senior convertible notes | — | — | (5 | ) | 5 | — | — | — | — | ||||||||||||||||||||||
Tax benefit related to stock-based compensation | — | — | 31,330 | — | — | — | — | 31,330 | |||||||||||||||||||||||
Deferred tax provision attributable to 2008 Pioneer Southwest initial public offering | — | — | (49,072 | ) | — | — | — | — | (49,072 | ) | |||||||||||||||||||||
Compensation costs: | |||||||||||||||||||||||||||||||
Vested compensation awards, net | 1,663 | 17 | (17 | ) | — | — | — | — | — | ||||||||||||||||||||||
Compensation costs included in net income | — | — | 46,173 | — | — | — | 864 | 47,037 | |||||||||||||||||||||||
Cash distributions to noncontrolling interests | — | — | — | — | — | — | (26,970 | ) | (26,970 | ) | |||||||||||||||||||||
Net income | — | — | — | — | 163,451 | — | 39,669 | 203,120 | |||||||||||||||||||||||
Other comprehensive activity: | |||||||||||||||||||||||||||||||
Deferred hedging activity, net of tax: | |||||||||||||||||||||||||||||||
Net hedge losses included in continuing operations | — | — | — | — | — | 3,130 | — | 3,130 | |||||||||||||||||||||||
Balance as of September 30, 2012 | 123,232 | $ | 1,348 | $ | 3,641,248 | $ | (504,140 | ) | $ | 2,485,935 | $ | — | $ | 175,718 | $ | 5,800,109 |
Nine Months Ended September 30, | ||||||||
2012 | 2011 | |||||||
Cash flows from operating activities: | ||||||||
Net income | $ | 203,120 | $ | 995,102 | ||||
Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||
Depletion, depreciation and amortization | 557,064 | 387,320 | ||||||
Exploration expenses, including dry holes | 52,574 | 5,228 | ||||||
Deferred income taxes | 241,608 | 270,657 | ||||||
(Gain) loss on disposition of assets, net | (57,973 | ) | 1,439 | |||||
Accretion of discount on asset retirement obligations | 6,994 | 5,930 | ||||||
Discontinued operations | 293,646 | (371,767 | ) | |||||
Interest expense | 26,812 | 23,412 | ||||||
Derivative related activity | 93,088 | (269,746 | ) | |||||
Amortization of stock-based compensation | 46,899 | 31,525 | ||||||
Amortization of deferred revenue | (31,494 | ) | (33,620 | ) | ||||
Other noncash items | (20,998 | ) | 3,480 | |||||
Change in operating assets and liabilities, net of effects from acquisitions and dispositions: | ||||||||
Accounts receivable, net | (7,946 | ) | (35,252 | ) | ||||
Income taxes receivable | (8,632 | ) | 28,588 | |||||
Inventories | (6,347 | ) | (115,961 | ) | ||||
Prepaid expenses | (6,772 | ) | (7,558 | ) | ||||
Other current assets | 7,898 | 8,520 | ||||||
Accounts payable | 23,554 | 83,632 | ||||||
Interest payable | (16,302 | ) | (25,053 | ) | ||||
Income taxes payable | (9,566 | ) | (1,807 | ) | ||||
Other current liabilities | (29,757 | ) | 45,969 | |||||
Net cash provided by operating activities | 1,357,470 | 1,030,038 | ||||||
Cash flows from investing activities: | ||||||||
Proceeds from disposition of assets, net of cash sold | 92,473 | 819,638 | ||||||
Payments for acquisition, net of cash acquired | (296,959 | ) | — | |||||
Investment in unconsolidated subsidiary | — | (89,620 | ) | |||||
Additions to oil and gas properties | (2,072,800 | ) | (1,319,131 | ) | ||||
Additions to other assets and other property and equipment, net | (238,803 | ) | (265,740 | ) | ||||
Net cash used in investing activities | (2,516,089 | ) | (854,853 | ) | ||||
Cash flows from financing activities: | ||||||||
Borrowings under long-term debt | 1,608,618 | 102,616 | ||||||
Principal payments on long-term debt | (596,000 | ) | (135,883 | ) | ||||
Distributions to noncontrolling interests | (26,970 | ) | (19,944 | ) | ||||
Payments of other liabilities | (894 | ) | (503 | ) | ||||
Exercise of long-term incentive plan stock options and employee stock purchases | 7,072 | 3,690 | ||||||
Purchases of treasury stock | (56,677 | ) | (40,326 | ) | ||||
Excess tax benefits from share-based payment arrangements | 31,330 | 28,123 | ||||||
Payment of financing fees | (6,430 | ) | (8,741 | ) | ||||
Dividends paid | (5,028 | ) | (4,812 | ) | ||||
Net cash provided by (used in) financing activities | 955,021 | (75,780 | ) | |||||
Net increase (decrease) in cash and cash equivalents | (203,598 | ) | 99,405 | |||||
Cash and cash equivalents, beginning of period | 537,484 | 111,160 | ||||||
Cash and cash equivalents, end of period | $ | 333,886 | $ | 210,565 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||
Revenues and other income: | ||||||||||||||||
Oil and gas | $ | 30,466 | $ | 36,395 | $ | 111,426 | $ | 118,137 | ||||||||
Interest and other | — | 224 | 20 | 5,195 | ||||||||||||
Gain (loss) on disposition of assets, net | 28,179 | (58 | ) | 28,157 | 645,241 | |||||||||||
58,645 | 36,561 | 139,603 | 768,573 | |||||||||||||
Costs and expenses: | ||||||||||||||||
Oil and gas production | 11,573 | 6,944 | 35,718 | 19,023 | ||||||||||||
Production and ad valorem taxes | 744 | 829 | 2,273 | 1,720 | ||||||||||||
Depletion, depreciation and amortization (a) | 3,134 | 18,043 | 32,673 | 54,717 | ||||||||||||
Impairment of oil and gas properties (a) (b) | — | — | 444,880 | — | ||||||||||||
Exploration and abandonments | 372 | 6,005 | 8,660 | 19,021 | ||||||||||||
General and administrative | 721 | 471 | 1,853 | 9,868 | ||||||||||||
Accretion of discount on asset retirement obligations (a) | 344 | 813 | 1,898 | 2,270 | ||||||||||||
Interest | — | — | (75 | ) | 773 | |||||||||||
Other | (26 | ) | 245 | 1,313 | 4,457 | |||||||||||
16,862 | 33,350 | 529,193 | 111,849 | |||||||||||||
Income (loss) from discontinued operations before income taxes | 41,783 | 3,211 | (389,590 | ) | 656,724 | |||||||||||
Current tax provision | (4,231 | ) | (9,338 | ) | (8,317 | ) | (35,872 | ) | ||||||||
Deferred tax (provision) benefit (a) | (2,902 | ) | 6,457 | 157,433 | (210,296 | ) | ||||||||||
Income (loss) from discontinued operations | $ | 34,650 | $ | 330 | $ | (240,474 | ) | $ | 410,556 |
(a) | Represents significant noncash components of discontinued operations. |
(b) | Represents the pretax noncash impairment of Barnett Shale field oil and gas properties that was recorded during the three months ended June 30, 2012. See Note O for additional information about Barnett Shale field impairment. |
September 30, 2012 | December 31, 2011 | |||||||
(in thousands) | ||||||||
Composition of assets included in discontinued operations held for sale: | ||||||||
Current assets (excluding cash and cash equivalents) | $ | 13,127 | $ | 10,465 | ||||
Property, plant and equipment | 351,736 | 53,025 | ||||||
Goodwill | 4,693 | — | ||||||
Deferred tax assets | 28,647 | 9,816 | ||||||
Other assets, net | 2,189 | 43 | ||||||
Total assets | $ | 400,392 | $ | 73,349 | ||||
Composition of liabilities included in discontinued operations held for sale: | ||||||||
Current liabilities | $ | 160 | $ | 11,689 | ||||
Deferred revenue | — | 34,320 | ||||||
Other liabilities | 5,759 | 29,892 | ||||||
Total liabilities | $ | 5,919 | $ | 75,901 |
Three Months Ended September 30, 2012 | Nine Months Ended September 30, 2012 | ||||||
(in thousands) | |||||||
Beginning capitalized exploratory costs | $ | 193,727 | $ | 107,596 | |||
Additions to exploratory costs pending the determination of proved reserves | 235,500 | 616,332 | |||||
Reclassification due to determination of proved reserves | (224,784 | ) | (491,199 | ) | |||
Exploratory well costs charged to exploration expense | (1,563 | ) | (29,849 | ) | |||
Ending capitalized exploratory costs | $ | 202,880 | $ | 202,880 |
September 30, 2012 | December 31, 2011 | ||||||
(in thousands, except project counts) | |||||||
Capitalized exploratory costs that have been suspended: | |||||||
One year or less | $ | 181,022 | $ | 107,596 | |||
More than one year | 21,858 | — | |||||
$ | 202,880 | $ | 107,596 | ||||
Number of projects with exploratory costs that have been suspended for a period greater than one year | 1 | — |
• | Level 1 – quoted prices for identical assets or liabilities in active markets. |
• | Level 2 – quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability (e.g., interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means. |
• | Level 3 – unobservable inputs for the asset or liability. |
Fair Value Measurement at the End of the Reporting Period Using | |||||||||||||||||
Quoted Prices in Active Markets for Identical Assets (Level 1) | Significant Other Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | Fair Value at September 30, 2012 | ||||||||||||||
(in thousands) | |||||||||||||||||
Recurring fair value measurements | |||||||||||||||||
Assets: | |||||||||||||||||
Trading securities | $ | 162 | $ | 157 | $ | — | $ | 319 | |||||||||
Commodity derivatives | — | 326,923 | — | 326,923 | |||||||||||||
Deferred compensation plan assets | 47,402 | — | — | 47,402 | |||||||||||||
Total assets | 47,564 | 327,080 | — | 374,644 | |||||||||||||
Liabilities: | |||||||||||||||||
Commodity derivatives | — | (31,219 | ) | $ | — | (31,219 | ) | ||||||||||
Interest rate derivatives | — | (11,534 | ) | — | (11,534 | ) | |||||||||||
Total liabilities | — | (42,753 | ) | — | (42,753 | ) | |||||||||||
Total recurring fair value measurements | $ | 47,564 | $ | 284,327 | $ | — | $ | 331,891 |
September 30, 2012 | December 31, 2011 | |||||||||||||||
Carrying Value | Fair Value | Carrying Value | Fair Value | |||||||||||||
(in thousands) | ||||||||||||||||
Long-term debt | $ | 3,562,070 | $ | 4,449,088 | $ | 2,528,905 | $ | 3,105,585 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||
Current | $ | 13,052 | $ | (3,035 | ) | $ | (6,927 | ) | $ | (8,075 | ) | |||||
Deferred | (21,438 | ) | (179,693 | ) | (241,608 | ) | (270,657 | ) | ||||||||
Income tax provision | $ | (8,386 | ) | $ | (182,728 | ) | $ | (248,535 | ) | $ | (278,732 | ) |
Three Months Ending December 31, | Twelve Months Ending December 31, | |||||||||||||||
2012 | 2013 | 2014 | 2015 | |||||||||||||
Collar contracts with short puts: | ||||||||||||||||
Volume (BBL) (a) | 53,110 | 54,029 | 60,000 | 26,000 | ||||||||||||
Average price per BBL: | ||||||||||||||||
Ceiling | $ | 118.85 | $ | 119.60 | $ | 117.06 | $ | 104.45 | ||||||||
Floor | $ | 85.09 | $ | 89.71 | $ | 92.67 | $ | 95.00 | ||||||||
Short put | $ | 69.44 | $ | 73.74 | $ | 76.58 | $ | 80.00 | ||||||||
Collar contracts: | ||||||||||||||||
Volume (BBL) | 2,000 | — | — | — | ||||||||||||
Average price per BBL: | ||||||||||||||||
Ceiling | $ | 127.00 | $ | — | $ | — | $ | — | ||||||||
Floor | $ | 90.00 | $ | — | $ | — | $ | — | ||||||||
Swap contracts: | ||||||||||||||||
Volume (BBL) (a) | 11,000 | 20,000 | — | — | ||||||||||||
Average price per BBL | $ | 89.34 | $ | 97.27 | $ | — | $ | — | ||||||||
Rollfactor swap contracts: | ||||||||||||||||
Volume (BBL) | — | 6,000 | — | — | ||||||||||||
NYMEX roll price (b) | $ | — | $ | 0.43 | $ | — | $ | — | ||||||||
Basis swap contracts: | ||||||||||||||||
Index swap volume (BBL) | 20,000 | — | — | — | ||||||||||||
Average price per BBL (c) | $ | (1.15 | ) | $ | — | $ | — | $ | — |
(a) | Subsequent to September 30, 2012, the Company converted NYMEX swap contracts for 17,000 BBLs per day of 2013 production with a price of $100.14 per BBL into collar contracts with short puts for 17,000 BBLs per day of 2013 production with a ceiling price of $120.29 per BBL, a floor price of $100.41 per BBL and a short put price of $75.99 per BBL. |
(b) | Represents swaps that fix the difference between (i) each day's price per BBL of WTI for the first nearby month less (ii) the price per BBL of WTI for the second nearby NYMEX month, multiplied by .6667; plus (iii) each day's price per BBL of WTI for the first nearby month less (iv) the price per BBL of WTI for the third nearby NYMEX month, multiplied by .3333. |
(c) | Basis differential price between Midland WTI and Cushing WTI. |
Three Months Ending December 31, | Twelve Months Ending December 31, | |||||||||||
2012 | 2013 | 2014 | ||||||||||
Collar contracts with short puts: | ||||||||||||
Volume (BBL) | 3,000 | 1,000 | 1,000 | |||||||||
Average price per BBL: | ||||||||||||
Ceiling | $ | 79.99 | $ | 112.00 | $ | 109.50 | ||||||
Floor | $ | 67.70 | $ | 95.00 | $ | 95.00 | ||||||
Short put | $ | 55.76 | $ | 80.00 | $ | 80.00 | ||||||
Swap contracts: | ||||||||||||
Volume (BBL) | 2,750 | — | — | |||||||||
Average price per BBL | $ | 67.85 | $ | — | $ | — |
(a) | Subsequent to September 30, 2012, the Company converted the 2013 collar contracts with short puts for 1,000 BBLs per day into collar contracts with short puts for 1,064 BBLs per day of 2013 natural gasoline production with a ceiling price of $105.28 per BBL, a floor price of $89.30 per BBL and a short put price of $75.20 per BBL. |
Three Months Ending December 31, | Twelve Months Ending December 31, | |||||||||||||||
2012 | 2013 | 2014 | 2015 | |||||||||||||
Collar contracts with short puts: | ||||||||||||||||
Volume (MMBTU) (a) | — | — | — | 155,000 | ||||||||||||
Price per MMBTU: | ||||||||||||||||
Ceiling | $ | — | $ | — | $ | — | $ | 4.97 | ||||||||
Floor | $ | — | $ | — | $ | — | $ | 4.00 | ||||||||
Short put | $ | — | $ | — | $ | — | $ | 3.00 | ||||||||
Collar contracts: | ||||||||||||||||
Volume (MMBTU) | 65,000 | 150,000 | — | — | ||||||||||||
Price per MMBTU: | ||||||||||||||||
Ceiling | $ | 6.60 | $ | 6.25 | $ | — | $ | — | ||||||||
Floor | $ | 5.00 | $ | 5.00 | $ | — | $ | — | ||||||||
Swap contracts: | ||||||||||||||||
Volume (MMBTU) (a) | 275,000 | 112,500 | 105,000 | — | ||||||||||||
Price per MMBTU | $ | 4.97 | $ | 5.62 | $ | 4.03 | $ | — | ||||||||
Basis swap contracts: | ||||||||||||||||
Volume (MMBTU) | 136,000 | 142,500 | — | — | ||||||||||||
Price per MMBTU | $ | (0.34 | ) | $ | (0.22 | ) | $ | — | $ | — |
(a) | Subsequent to September 30, 2012, the Company entered into additional (i) 2013 swap contracts for 50,000 MMBTU per day priced at $4.01 per MMBTU and (ii) 2015 collar contracts with short puts for 70,000 MMBTU per day with a ceiling price of $5.35 per MMBTU, a floor price of $4.00 per MMBTU and a short put price of $3.00 per MMBTU. |
Three Months Ending December 31, | Twelve Months Ending December 31, | ||||||
2012 | 2013 | ||||||
Average Daily Gas Production Associated with Marketing Derivatives: | |||||||
Basis swap contracts: | |||||||
Index swap volume (MMBTU) | 43,370 | 9,863 | |||||
Price differential ($/MMBTU) | $ | 0.24 | $ | 0.25 | |||
Average Daily Gas Production Associated with Basis Transfer Derivatives: | |||||||
Basis swap contracts: | |||||||
Short index swap volume (MMBTU) | 1,685 | — | |||||
NGI-So Cal Border Monthly price differential to NYMEX HH ($/MMBTU) | $ | 0.12 | $ | — | |||
Long index swap volume (MMBTU) | (1,685 | ) | — | ||||
IF-HSC price differential to NYMEX HH ($/MMBTU) | $ | (0.05 | ) | $ | — |
Fair Value of Derivative Instruments as of September 30, 2012 | ||||||||||||
Asset Derivatives (a) | Liability Derivatives (a) | |||||||||||
Type | Balance Sheet Location | Fair Value | Balance Sheet Location | Fair Value | ||||||||
(in thousands) | (in thousands) | |||||||||||
Derivatives not designated as hedging instruments | ||||||||||||
Commodity price derivatives | Derivatives - current | $ | 234,231 | Derivatives - current | $ | 23,145 | ||||||
Commodity price derivatives | Derivatives - noncurrent | 108,819 | Derivatives - noncurrent | 24,201 | ||||||||
Interest rate derivatives | Derivatives - noncurrent | — | Derivatives - noncurrent | 11,534 | ||||||||
$ | 343,050 | $ | 58,880 |
Fair Value of Derivative Instruments as of December 31, 2011 | ||||||||||||
Asset Derivatives (a) | Liability Derivatives (a) | |||||||||||
Type | Balance Sheet Location | Fair Value | Balance Sheet Location | Fair Value | ||||||||
(in thousands) | (in thousands) | |||||||||||
Derivatives not designated as hedging instruments | ||||||||||||
Commodity price derivatives | Derivatives - current | $ | 248,809 | Derivatives - current | $ | 68,735 | ||||||
Interest rate derivatives | Derivatives - current | — | Derivatives - current | 15,654 | ||||||||
Commodity price derivatives | Derivatives - noncurrent | 257,368 | Derivatives - noncurrent | 47,689 | ||||||||
$ | 506,177 | $ | 132,078 |
(a) | Derivative assets and liabilities shown in the tables above are presented as gross assets and liabilities, without regard to master netting arrangements which are considered in the presentations of derivative assets and liabilities in the accompanying consolidated balance sheets. |
Derivatives in Cash Flow Hedging | Location of Gain/(Loss) Reclassified from | Amount of Gain/(Loss) Reclassified from AOCI into Earnings | ||||||||||||||||
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||||
Relationships | AOCI into Earnings | 2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||||
Commodity price derivatives | Oil and gas revenue | $ | — | $ | 8,295 | $ | (3,156 | ) | $ | 24,627 | ||||||||
Interest rate derivatives | Interest expense | — | (71 | ) | (1,699 | ) | (209 | ) | ||||||||||
Total | $ | — | $ | 8,224 | $ | (4,855 | ) | $ | 24,418 |
Amount of Gain (Loss) Recognized in Earnings on Derivatives | ||||||||||||||||||
Derivatives Not Designated as Hedging | Location of Gain (Loss) Recognized in | Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
Instruments | Earnings on Derivatives | 2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||||
Commodity price derivatives | Derivative gains (losses), net | $ | (118,795 | ) | $ | 407,407 | $ | 267,806 | $ | 380,030 | ||||||||
Interest rate derivatives | Derivative gains (losses), net | (5,199 | ) | (6,335 | ) | (24,238 | ) | 6,088 | ||||||||||
Total | $ | (123,994 | ) | $ | 401,072 | $ | 243,568 | $ | 386,118 |
Net Assets (Liabilities) | ||||
(in thousands) | ||||
Citibank, N.A. | $ | 66,329 | ||
JP Morgan Chase | 57,419 | |||
Barclays Capital | 32,920 | |||
J. Aron & Company | 20,846 | |||
BNP Paribas | 20,061 | |||
BMO Financial Group | 19,187 | |||
Credit Suisse | 16,605 | |||
Toronto Dominion | 15,144 | |||
Societe Generale | 13,218 | |||
Morgan Stanley | 8,852 | |||
Merrill Lynch | 7,726 | |||
Den Norske Bank | 6,161 | |||
Credit Agricole | 2,099 | |||
Wells Fargo Bank, N.A. | 756 | |||
BP Corporation North America | 462 | |||
Macquarie Bank | 454 | |||
Vitol | 154 | |||
Royal Bank of Canada | (362 | ) | ||
Deutsche Bank | (766 | ) | ||
UBS | (3,095 | ) | ||
Total | $ | 284,170 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||
Beginning asset retirement obligations | $ | 145,457 | $ | 151,970 | $ | 136,742 | $ | 152,291 | ||||||||
Liabilities assumed in acquisitions | — | — | 8,515 | 6 | ||||||||||||
New wells placed on production | 1,251 | 1,132 | 3,662 | 3,206 | ||||||||||||
Changes in estimates | 48 | (5,453 | ) | 1,651 | (5,331 | ) | ||||||||||
Liabilities reclassified to discontinued operations held for sale | (5,919 | ) | — | (5,919 | ) | — | ||||||||||
Disposition of wells | (2,536 | ) | — | (2,536 | ) | (448 | ) | |||||||||
Liabilities settled | (4,506 | ) | (2,808 | ) | (13,248 | ) | (10,277 | ) | ||||||||
Accretion of discount from continuing operations | 2,369 | 1,993 | 6,994 | 5,930 | ||||||||||||
Accretion of discount from integrated services (a) | 23 | — | 77 | — | ||||||||||||
Accretion of discount from discontinued operations | 127 | 813 | 376 | 2,270 | ||||||||||||
Ending asset retirement obligations | $ | 136,314 | $ | 147,647 | $ | 136,314 | $ | 147,647 |
(a) | Accretion of discount from integrated services includes Premier Silica accretion expense, which is recorded as a reduction in third-party income from vertical integration services in interest and other income in the Company's accompanying consolidated statements of operations. See Note M for more information about interest and other income. |
Restricted Stock Equity Awards | Restricted Stock Liability Awards | Performance Units | Stock Options | Pioneer Southwest LTIP Restricted Units | Pioneer Southwest LTIP Phantom Units | |||||||||||||
Outstanding at December 31, 2011 | 1,857,612 | 322,925 | 114,128 | 564,044 | 7,492 | 65,157 | ||||||||||||
Awards granted | 912,543 | 240,524 | 47,875 | 98,819 | 7,496 | 37,487 | ||||||||||||
Awards vested | (1,220,841 | ) | (127,919 | ) | — | — | (7,492 | ) | — | |||||||||
Options exercised | — | — | — | (190,377 | ) | — | — | |||||||||||
Awards forfeited | (21,472 | ) | (18,360 | ) | — | — | — | — | ||||||||||
Outstanding as of September 30, 2012 | 1,527,842 | 417,170 | 162,003 | 472,486 | 7,496 | 102,644 |
Three Months Ended September 30, 2012 | Nine Months Ended September 30, 2012 | |||||||||||||||||||||||
Continuing Operations | Discontinued Operations | Total | Continuing Operations | Discontinued Operations | Total | |||||||||||||||||||
(in thousands) | ||||||||||||||||||||||||
Net income (loss) attributable to common stockholders | $ | (15,426 | ) | $ | 34,650 | $ | 19,224 | $ | 403,925 | $ | (240,474 | ) | $ | 163,451 | ||||||||||
Participating basic earnings | — | (357 | ) | (357 | ) | (2,499 | ) | — | (2,499 | ) | ||||||||||||||
Basic net income (loss) attributable to common stockholders | (15,426 | ) | 34,293 | 18,867 | 401,426 | (240,474 | ) | 160,952 | ||||||||||||||||
Reallocation of participating earnings | — | — | — | 134 | — | 134 | ||||||||||||||||||
Diluted income (loss) attributable to common stockholders | $ | (15,426 | ) | $ | 34,293 | $ | 18,867 | $ | 401,560 | $ | (240,474 | ) | $ | 161,086 |
Three Months Ended September 30, 2011 | Nine Months Ended September 30, 2011 | |||||||||||||||||||||||
Continuing Operations | Discontinued Operations | Total | Continuing Operations | Discontinued Operations | Total | |||||||||||||||||||
(in thousands) | ||||||||||||||||||||||||
Net income attributable to common stockholders | $ | 351,134 | $ | 330 | $ | 351,464 | $ | 535,079 | $ | 410,556 | $ | 945,635 | ||||||||||||
Participating basic earnings | (6,791 | ) | (6 | ) | (6,797 | ) | (9,725 | ) | (7,461 | ) | (17,186 | ) | ||||||||||||
Basic income attributable to common stockholders | 344,343 | 324 | 344,667 | 525,354 | 403,095 | 928,449 | ||||||||||||||||||
Reallocation of participating earnings | 189 | — | 189 | 259 | 199 | 458 | ||||||||||||||||||
Diluted income attributable to common stockholders | $ | 344,532 | $ | 324 | $ | 344,856 | $ | 525,613 | $ | 403,294 | $ | 928,907 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||
(in thousands) | ||||||||||||
Weighted average common shares outstanding: | ||||||||||||
Basic | 123,111 | 116,281 | 122,874 | 116,122 | ||||||||
Dilutive common stock options (a) | — | 166 | 196 | 181 | ||||||||
Convertible senior notes dilution (a) | — | 185 | 2,866 | 1,618 | ||||||||
Contingently issuable performance unit shares (a) | — | 443 | 175 | 429 | ||||||||
Diluted | 123,111 | 117,075 | 126,111 | 118,350 |
(a) | The following common share equivalents were excluded from the weighted average diluted shares for the three months ended September 30, 2012 because they would have been anti-dilutive to the loss recorded for the period: 179,449 outstanding options to purchase the Company's common stock, 184,545 common shares attributable to unvested performance units and 3,311,845 common shares issuable if holders of the Company's 2.875% Convertible Senior Notes had exercised their conversion rights (see Note G). Options to purchase 185,722 shares of the Company's common stock were excluded from the diluted income per share calculations for the nine months ended September 30, 2012 because they would have been anti-dilutive to the calculation. |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||
Equity in income of unconsolidated affiliate (a) | $ | 9,629 | $ | 1,641 | $ | 24,471 | $ | 2,442 | ||||||||
Alaskan Petroleum Production Tax credits and refunds (b) | 3,979 | 95 | 15,825 | 27,547 | ||||||||||||
Third-party income from vertical integration services (c) | 3,465 | 3,612 | 6,194 | 11,524 | ||||||||||||
Other income | 1,372 | 1,596 | 3,607 | 5,931 | ||||||||||||
Deferred compensation plan income | 204 | 288 | 1,727 | 1,454 | ||||||||||||
Interest income | 84 | 79 | 1,400 | 480 | ||||||||||||
Total interest and other income | $ | 18,733 | $ | 7,311 | $ | 53,224 | $ | 49,378 |
(a) | Represents the Company's equity in the earnings of EFS Midstream LLC ("EFS Midstream"), which owns and operates gas and liquids gathering, treating and transportation assets in the Eagle Ford Shale area of South Texas. |
(b) | The Company earns Alaskan Petroleum Production Tax ("PPT") credits on qualifying capital expenditures. The Company recognizes income from PPT credits when they are realized through cash refunds or as reductions in production and ad valorem taxes if realizable as offsets to PPT expense. |
(c) | Third-party income from vertical integration services reflects earnings from third-party working interest owners in Company-operated wells in which the Company provided fracture stimulation, drilling and related services. |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
(in thousands) | ||||||||||||||||
Transportation commitment charges (a) | $ | 9,694 | $ | 5,141 | $ | 27,374 | $ | 16,101 | ||||||||
Above market drilling rig and well services equipment rates (b) | 12,720 | 4,632 | 23,466 | 15,201 | ||||||||||||
Terminated drilling rig contract charges (c) | 6,807 | — | 15,768 | — | ||||||||||||
Other | 2,340 | 4,951 | 10,136 | 9,867 | ||||||||||||
Inventory valuation charges (d) | 46 | 1,745 | 6,093 | 2,332 | ||||||||||||
Premier Silica acquisition costs | 246 | — | 2,419 | — | ||||||||||||
Contingency and environmental accrual adjustments | 70 | 588 | 772 | 3,470 | ||||||||||||
Total other expense | $ | 31,923 | $ | 17,057 | $ | 86,028 | $ | 46,971 |
(a) | Primarily represents firm transportation payments on excess pipeline capacity commitments. |
(b) | Primarily represents expenses attributable to the portion of Pioneer's contracted drilling rig rates that are above current market rates and idle drilling rig and fracture stimulation fleet fees, neither of which are charged to joint operations. |
(c) | Primarily represents charges to terminate rig contracts that are not required to meet planned drilling activities. |
(d) | Represents valuation charges on excess materials and supplies inventories; principally related to dry gas assets. |
• | Net income attributable to common stockholders for the third quarter of 2012 was $19.2 million ($0.15 per diluted share), as compared to $351.5 million ($2.95 per diluted share) for the third quarter of 2011. The decrease in net income attributable to common stockholders is primarily comprised of a $398.2 million decrease in net income (loss) from continuing operations, which includes: |
▪ | recognizing net derivative losses of $124.0 million for the three months ended September 30, 2012, as compared to net derivative gains of $401.1 million for the three months ended September 30, 2011; |
▪ | a $65.9 million increase in DD&A expense, primarily due to increased sales volumes; |
▪ | a $64.1 million increase in oil and gas production costs, primarily due to increases in variable lease operating expenses and third-party transportation fees due to higher sales volumes; partially offset by |
▪ | a $174.3 million decline in income tax provisions attributable to continuing operations; and |
▪ | a $121.3 million increase in oil and gas revenues as a result of an increase in sales volumes, partially offset by lower average commodity prices. |
• | During the third quarter of 2012, average daily sales volumes increased by 28 percent to 153,016 BOEPD, as compared to 119,597 BOEPD during the third quarter of 2011. The increase in third quarter 2012 average daily sales volumes, as compared to the third quarter of 2011, was primarily due to the Company's successful drilling program during the last three months of 2011 and the first nine months of 2012; |
• | Average reported oil, NGL and gas prices decreased during the third quarter of 2012 to $89.87 per BBL, $31.28 per BBL and $2.62 per MCF, respectively, as compared to $92.11 per BBL, $48.33 per BBL and $4.05 per MCF, respectively, in the third quarter of 2011; |
• | Average oil and gas production costs per BOE increased to $12.55 for the third quarter of 2012, as compared to $10.23 for the third quarter of 2011, primarily due to increases in lease operating expenses, third party transportation charges and net natural gas plant charges. The increase in lease operating expenses is primarily due to increases in salt water disposal costs (principally comprised of water hauling fees) and higher repair and maintenance activity during the third quarter of 2012. The increase in third-party transportation costs is primarily due to gathering, treating and transportation costs associated with increasing sales volumes in the Eagle Ford Shale field. Net natural gas plant charges increased primarily due to a reduction in third-party gas volumes in Company-owned facilities as a result of lower gas and NGL prices being realized on the volumes retained as processing fees. See "Results of Operations," below for more information about changes in production costs; |
• | Net cash provided by operating activities decreased to $432.1 million for the three months ended September 30, 2012, as compared to $465.6 million for the three months ended September 30, 2011. The $33.5 million decrease in net cash provided by operating activities is primarily due to working capital changes during the third quarter of 2012; |
• | In August 2012, the Company completed the sale of Pioneer South Africa for net cash proceeds of $15.9 million, including normal closing adjustments. The Company recorded a pretax gain of $28.6 million on the sale of Pioneer South Africa in income (loss) from discontinued operations for the three and nine months ended September 30, 2012; |
• | In early August 2012, the Company announced plans to pursue a joint venture partner to accelerate the development of the horizontal Wolfcamp Shale play in the southern 200,000 acres of the Company's total prospective position. See "Operations and Drilling Highlights" for more information about the Company's Wolfcamp Shale play; |
• | In early September 2012, the Company announced plans to divest of its properties in the Barnett Shale field. The Company has opened a data room and is targeting completing the transaction during the first quarter of 2013. Accordingly, the Company has classified its (i) Barnett Shale assets and liabilities as discontinued operations held for sale in the accompanying consolidated balance sheet as of September 30, 2012 and (ii) Barnett Shale results of operations as income from discontinued operations, net of tax in the accompanying consolidated statements of operations (representing a recasting of the Barnett Shale field results of operations for the three and nine months ended September 30, 2011 and the six months ended June 30, 2012, which were originally classified as continuing operations). See Note C of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for more information about discontinued operations; |
• | As of September 30, 2012, the Company's net debt to book capitalization was 36 percent, as compared to 26 percent as |
Oil (BBLs) | NGLs (BBLs) | Gas (MCF) | Total (BOE) | |||||||||
Permian Basin | 43,186 | 12,926 | 59,855 | 66,088 | ||||||||
South Texas - Eagle Ford Shale | 9,267 | 6,616 | 57,132 | 25,405 | ||||||||
Raton Basin | — | — | 151,648 | 25,275 | ||||||||
Mid-Continent | 3,213 | 6,979 | 47,802 | 18,159 | ||||||||
South Texas - Edwards and Austin Chalk | 78 | 1 | 37,921 | 6,399 | ||||||||
Alaska | 4,325 | — | — | 4,325 | ||||||||
Other | 1 | 4 | 110 | 23 | ||||||||
60,070 | 26,526 | 354,468 | 145,674 |
Acquisition Costs | Exploration | Development | Asset Retirement | |||||||||||||||||||||
Proved | Unproved | Costs | Costs | Obligations | Total | |||||||||||||||||||
(in thousands) | ||||||||||||||||||||||||
Permian Basin | $ | 3,099 | $ | 56,157 | $ | 280,853 | $ | 1,273,779 | $ | 2,375 | $ | 1,616,263 | ||||||||||||
South Texas - Eagle Ford Shale | — | 9,740 | 131,179 | 4,973 | 62 | 145,954 | ||||||||||||||||||
Raton Basin | — | — | 6,397 | 6,469 | — | 12,866 | ||||||||||||||||||
Mid-Continent | — | 4,153 | 3,524 | 14,712 | — | 22,389 | ||||||||||||||||||
South Texas - Edwards and Austin Chalk | — | 130 | 3,525 | 5,845 | — | 9,500 | ||||||||||||||||||
Barnett Shale | 8,673 | 7,732 | 171,476 | 47,528 | 337 | 235,746 | ||||||||||||||||||
Alaska | — | — | 62,522 | 88,641 | 2,532 | 153,695 | ||||||||||||||||||
Other | 47 | 39,967 | 1,777 | 9 | — | 41,800 | ||||||||||||||||||
$ | 11,819 | $ | 117,879 | $ | 661,253 | $ | 1,441,956 | $ | 5,306 | $ | 2,238,213 |
Development Drilling | |||||||||||||||
Beginning Wells in Progress | Wells Spud | Successful Wells | Unsuccessful Wells | Ending Wells in Progress | |||||||||||
Permian Basin | 161 | 500 | 547 | 8 | 106 | ||||||||||
Raton Basin | 5 | — | 4 | 1 | — | ||||||||||
Barnett Shale | — | 4 | 4 | — | — | ||||||||||
Alaska | 1 | 3 | 2 | — | 2 | ||||||||||
Total United States | 167 | 507 | 557 | 9 | 108 |
Exploration/Extension Drilling | |||||||||||||||
Beginning Wells in Progress | Wells Spud | Successful Wells | Unsuccessful Wells | Ending Wells in Progress | |||||||||||
Permian Basin | — | 31 | 16 | — | 15 | ||||||||||
South Texas - Eagle Ford Shale | 39 | 99 | 102 | — | 36 | ||||||||||
Mid-Continent | 5 | — | — | 5 | — | ||||||||||
Barnett Shale | 26 | 27 | 39 | — | 14 | ||||||||||
Alaska | 1 | 2 | — | 1 | 2 | ||||||||||
Total United States | 71 | 159 | 157 | 6 | 67 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||
Oil (BBLs) | 63,125 | 41,463 | 60,070 | 36,943 | ||||||||
NGLs (BBLs) | 30,352 | 21,748 | 26,526 | 20,132 | ||||||||
Gas (MCF) | 357,232 | 338,321 | 354,468 | 328,464 | ||||||||
Total (BOE) | 153,016 | 119,597 | 145,674 | 111,819 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Average reported prices: | ||||||||||||||||
Oil (per BBL) | $ | 89.87 | $ | 92.11 | $ | 92.83 | $ | 97.06 | ||||||||
NGL (per BBL) | $ | 31.28 | $ | 48.33 | $ | 35.10 | $ | 46.59 | ||||||||
Gas (per MCF) | $ | 2.62 | $ | 4.05 | $ | 2.39 | $ | 4.02 | ||||||||
Total (per BOE) | $ | 49.40 | $ | 52.18 | $ | 50.48 | $ | 52.27 | ||||||||
Average realized prices: | ||||||||||||||||
Oil (per BBL) | $ | 88.05 | $ | 86.96 | $ | 91.11 | $ | 91.28 | ||||||||
NGL (per BBL) | $ | 31.28 | $ | 48.33 | $ | 35.10 | $ | 46.59 | ||||||||
Gas (per MCF) | $ | 2.62 | $ | 4.05 | $ | 2.39 | $ | 4.02 | ||||||||
Total (per BOE) | $ | 48.65 | $ | 50.39 | $ | 49.77 | $ | 50.36 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Lease operating expenses | $ | 9.36 | $ | 8.14 | $ | 8.20 | $ | 7.94 | ||||||||
Third-party transportation charges | 1.82 | 1.16 | 1.77 | 1.09 | ||||||||||||
Net natural gas plant charges | 0.61 | 0.14 | 0.51 | 0.09 | ||||||||||||
Workover costs | 0.76 | 0.79 | 0.79 | 0.87 | ||||||||||||
Total production costs | $ | 12.55 | $ | 10.23 | $ | 11.27 | $ | 9.99 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Ad valorem taxes | $ | 1.37 | $ | 1.20 | $ | 1.33 | $ | 1.37 | ||||||||
Production taxes | 2.11 | 2.23 | 2.12 | 2.10 | ||||||||||||
Total ad valorem and production taxes | $ | 3.48 | $ | 3.43 | $ | 3.45 | $ | 3.47 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2012 | 2011 | 2012 | 2011 | |||||||||||||
Geological and geophysical | $ | 14,288 | $ | 12,380 | $ | 56,672 | $ | 36,979 | ||||||||
Exploratory dry holes | 1,564 | 124 | 29,851 | 628 | ||||||||||||
Leasehold abandonments and other | 10,800 | 1,517 | 22,391 | 5,202 | ||||||||||||
$ | 26,652 | $ | 14,021 | $ | 108,914 | $ | 42,809 |
Derivative Contract Net Assets | ||||||||||||
Commodities | Interest Rates | Total | ||||||||||
(in thousands) | ||||||||||||
Fair value of contracts outstanding as of December 31, 2011 | $ | 389,753 | $ | (15,654 | ) | $ | 374,099 | |||||
Changes in contract fair value (a) | 267,806 | (24,238 | ) | 243,568 | ||||||||
Contract maturities | (215,262 | ) | — | (215,262 | ) | |||||||
Contract terminations | (146,593 | ) | 28,358 | (118,235 | ) | |||||||
Fair value of contracts outstanding as of September 30, 2012 | $ | 295,704 | $ | (11,534 | ) | $ | 284,170 |
(a) | At inception, new derivative contracts entered into by the Company had no intrinsic value. |
Three Months Ending December 31, | Year Ending December 31, | Liability Fair Value at September 30. | ||||||||||||||||||||||||||||||
2012 | 2013 | 2014 | 2015 | 2016 | Thereafter | Total | 2012 | |||||||||||||||||||||||||
($ in thousands) | ||||||||||||||||||||||||||||||||
Total Debt: | ||||||||||||||||||||||||||||||||
Fixed rate principal maturities (a) | $ | — | $ | 479,908 | $ | — | $ | — | $ | 455,385 | $ | 2,234,600 | $ | 3,169,893 | $ | (3,982,769 | ) | |||||||||||||||
Weighted average interest rate | 6.02 | % | 5.41 | % | 5.26 | % | 6.78 | % | 6.88 | % | 5.89 | % | ||||||||||||||||||||
Variable rate principal maturities: | ||||||||||||||||||||||||||||||||
Pioneer Natural Resources credit facility | $ | — | $ | — | $ | — | $ | — | $ | 360,000 | $ | — | $ | 360,000 | $ | (378,731 | ) | |||||||||||||||
Weighted average interest rate | 2.07 | % | 2.10 | % | 2.25 | % | 2.55 | % | 2.78 | % | — | |||||||||||||||||||||
Pioneer Southwest credit facility | $ | — | $ | — | $ | — | $ | — | $ | — | $ | 88,000 | $ | 88,000 | $ | (87,588 | ) | |||||||||||||||
Weighted average interest rate | 1.94 | % | 1.98 | % | 2.13 | % | 2.42 | % | 2.66 | % | 2.89 | % | ||||||||||||||||||||
Interest Rate Swaps: | ||||||||||||||||||||||||||||||||
Notional debt amount | $ | — | $ | — | $ | — | $ | 250,000 | $ | — | $ | — | $ | 250,000 | $ | (11,534 | ) | |||||||||||||||
Fixed rate payable (%) | — | % | — | % | — | % | 3.21 | % | — | % | — | % | ||||||||||||||||||||
Variable rate receivable (%) | — | % | — | % | — | % | 2.76 | % | — | % | — | % |
(a) | Represents maturities of principal amounts excluding debt issuance discounts and net deferred fair value hedge losses. |
Three Months Ending December 31, | Year Ending December 31, | Asset (Liability) Fair Value at September 30, | ||||||||||||||||||
2012 | 2013 | 2014 | 2015 | 2012 | ||||||||||||||||
(in thousands) | ||||||||||||||||||||
Oil Derivatives: | ||||||||||||||||||||
Average daily notional BBL volumes: | ||||||||||||||||||||
Collar contracts with short puts (a) | 53,110 | 54,029 | 60,000 | 26,000 | $ | 100,822 | ||||||||||||||
Weighted average ceiling price per BBL | $ | 118.85 | $ | 119.60 | $ | 117.06 | $ | 104.45 | ||||||||||||
Weighted average floor price per BBL | $ | 85.09 | $ | 89.71 | $ | 92.67 | $ | 95.00 | ||||||||||||
Weighted average short put price per BBL | $ | 69.44 | $ | 73.74 | $ | 76.58 | $ | 80.00 | ||||||||||||
Collar contracts | 2,000 | — | — | — | $ | 584 | ||||||||||||||
Weighted average ceiling price per BBL | $ | 127.00 | $ | — | $ | — | $ | — | ||||||||||||
Weighted average floor price per BBL | $ | 90.00 | $ | — | $ | — | $ | — | ||||||||||||
Swap contracts (a) | 11,000 | 20,000 | — | — | $ | 22,424 | ||||||||||||||
Weighted average fixed price per BBL | $ | 89.34 | $ | 97.27 | $ | — | $ | — | ||||||||||||
Average forward NYMEX oil prices (b) | $ | 86.24 | $ | 88.71 | $ | 88.50 | $ | 86.69 | ||||||||||||
Rollfactor swap contracts | — | 6,000 | — | — | $ | 903 | ||||||||||||||
Weighted average fixed price per BBL (c) | $ | — | $ | 0.43 | $ | — | $ | — | ||||||||||||
Average forward rollfactor prices (b) | $ | — | $ | (0.27 | ) | $ | — | $ | — | |||||||||||
Basis swap contracts | 20,000 | — | — | — | $ | 617 | ||||||||||||||
Weighted average fixed price per BBL | $ | (1.15 | ) | $ | — | $ | — | $ | — | |||||||||||
Average forward basis differential prices (d) | $ | (4.30 | ) | $ | — | $ | — | $ | — | |||||||||||
NGL Derivatives: | ||||||||||||||||||||
Average daily notional BBL volumes: | ||||||||||||||||||||
Collar contracts with short puts | 3,000 | 1,000 | 1,000 | — | $ | 6,387 | ||||||||||||||
Weighted average ceiling price per BBL | $ | 79.99 | $ | 112.00 | $ | 109.50 | $ | — | ||||||||||||
Weighted average floor price per BBL | $ | 67.70 | $ | 95.00 | $ | 95.00 | $ | — | ||||||||||||
Weighted average short put price per BBL | $ | 55.76 | $ | 80.00 | $ | 80.00 | $ | — | ||||||||||||
Swap contracts (e) | 2,750 | — | — | — | $ | (968 | ) | |||||||||||||
Weighted average fixed price per BBL | $ | 67.85 | $ | — | $ | — | $ | — | ||||||||||||
Average forward NGL prices (f) | $ | 64.27 | $ | 86.20 | $ | 83.76 | $ | — | ||||||||||||
Gas Derivatives: | ||||||||||||||||||||
Average daily notional MMBTU volumes: | ||||||||||||||||||||
Collar contracts with short puts (g) | — | — | — | 155,000 | $ | (11,429 | ) | |||||||||||||
Weighted average ceiling price per MMBTU | $ | — | $ | — | $ | — | $ | 4.97 | ||||||||||||
Weighted average floor price per MMBTU | $ | — | $ | — | $ | — | $ | 4.00 | ||||||||||||
Weighted average short put price per MMBTU | $ | — | $ | — | $ | — | $ | 3.00 | ||||||||||||
Collar contracts | 65,000 | 150,000 | — | — | $ | 76,590 | ||||||||||||||
Weighted average ceiling price per MMBTU | $ | 6.60 | $ | 6.25 | $ | — | $ | — | ||||||||||||
Weighted average floor price per MMBTU | $ | 5.00 | $ | 5.00 | $ | — | $ | — | ||||||||||||
Swap contracts (g) | 275,000 | 112,500 | 105,000 | — | $ | 108,198 | ||||||||||||||
Weighted average fixed price per MMBTU | $ | 4.97 | $ | 5.62 | $ | 4.03 | $ | — | ||||||||||||
Average forward NYMEX gas prices (b) | $ | 3.69 | $ | 3.90 | $ | 4.22 | $ | 4.40 | ||||||||||||
Basis swap contracts | 136,000 | 142,500 | — | — | $ | (8,315 | ) | |||||||||||||
Weighted average fixed price per MMBTU | $ | (0.34 | ) | $ | (0.22 | ) | $ | — | $ | — | ||||||||||
Average forward basis differential prices (h) | $ | (0.10 | ) | $ | (0.11 | ) | $ | — | $ | — |
(a) | Subsequent to September 30, 2012, the Company converted NYMEX swap contracts for 17,000 BBLs per day of 2013 production with a price of $100.14 per BBL into collar contracts with short puts for 17,000 BBLs per day of 2013 production with a ceiling price of $120.29 per BBL, a floor price of $100.41 per BBL and a short put price of $75.99 per BBL. |
(b) | The average forward NYMEX oil and gas prices are based on October 31, 2012 market quotes. |
(c) | Represents swaps that fix the difference between (i) each day's price per BBL of WTI for the first nearby month less (ii) the price per BBL of WTI for the second nearby NYMEX month, multiplied by .6667; plus (iii) each day's price per BBL of WTI for the first nearby month less (iv) the price per BBL of WTI for the third nearby NYMEX month, multiplied by .3333. |
(d) | The average forward basis differential prices are based on October 31, 2012 market quotes for basis differentials between Midland WTI and Cushing WTI. |
(e) | Subsequent to September 30, 2012, the Company converted 2013 collar contracts with short puts for 1,000 BBLs per day into collar contracts with short puts for 1,064 BBLs per day of 2013 natural gasoline production with a ceiling price of $105.28 per BBL, a floor price of $89.30 per BBL and a short put price of $75.20 per BBL. |
(f) | Forward component NGL prices are derived from active-market NGL component price quotes as of October 31, 2012. |
(g) | Subsequent to September 30, 2012, the Company entered into additional (i) 2013 swap contracts for 50,000 MMBTU per day priced at $4.01 per MMBTU and (ii) 2015 collar contracts with short puts for 70,000 MMBTU per day with a ceiling price of $5.35 per MMBTU, a floor price of $4.00 per MMBTU and a short put price of $3.00 per MMBTU. |
(h) | The average forward basis differential prices are based on October 31, 2012 market quotes for basis differentials between the relevant index prices and NYMEX-quoted forward prices. |
Three Months Ending December 31, | Year Ending December 31, | Asset Fair Value at September 30, | ||||||||||
2012 | 2013 | 2012 | ||||||||||
(in thousands) | ||||||||||||
Average Daily Gas Production Associated with Marketing Derivatives (MMBTU): | ||||||||||||
Basis swap contracts: | ||||||||||||
Index swap volume | 43,370 | 9,863 | $ | (110 | ) | |||||||
Price differential ($/MMBTU) | $ | 0.24 | 0.25 | |||||||||
Average forward basis differential prices (a) | $ | 0.27 | $ | 0.26 | ||||||||
Average Daily Gas Production Associated with Basis Transfer Derivatives (MMBTU): | ||||||||||||
Basis swap contracts: | ||||||||||||
Index swap volume | 1,685 | — | $ | 1 | ||||||||
NGI-So Cal Border Monthly price differential to NYMEX HH ($/MMBTU) | $ | 0.12 | — | |||||||||
Index swap volume | (1,685 | ) | — | |||||||||
IF-HSC price differential to NYMEX HH ($/MMBTU) | $ | (0.05 | ) | — | ||||||||
Average forward basis differential prices (a) | $ | 0.24 | $ | — |
(a) | The average forward basis differential prices are based on October 31, 2012 market quotes for basis differentials between the relevant index prices and NYMEX-quoted forward prices. |
Period | Total Number of Shares (or Units) Purchased (a) | Average Price Paid per Share (or Unit) | Total Number of Shares (or Units) Purchased As Part of Publicly Announced Plans or Programs | Approximate Dollar Amount of Shares that May Yet Be Purchased under Plans or Programs | ||||||||||
July 2012 | — | $ | — | — | ||||||||||
August 2012 | 3,638 | $ | 98.86 | — | ||||||||||
September 2012 | — | $ | — | — | ||||||||||
Total | 3,638 | $ | 98.86 | — | $ | — |
(a) | Consists of shares purchased from employees in order for the employee to satisfy tax withholding payments related to share-based awards that vested during the period. |
Exhibit Number | Description | |||
31.1 | (a) — | Chief Executive Officer certification under Section 302 of Sarbanes-Oxley Act of 2002. | ||
31.2 | (a) — | Chief Financial Officer certification under Section 302 of Sarbanes-Oxley Act of 2002. | ||
32.1 | (b) — | Chief Executive Officer certification under Section 906 of Sarbanes-Oxley Act of 2002. | ||
32.2 | (b) — | Chief Financial Officer certification under Section 906 of Sarbanes-Oxley Act of 2002. | ||
95.1 | (a) — | Mine Safety Disclosures | ||
101.INS | (a) — | XBRL Instance Document. | ||
101.SCH | (a) — | XBRL Taxonomy Extension Schema. | ||
101.CAL | (a) — | XBRL Taxonomy Extension Calculation Linkbase Document. | ||
101.DEF | (a) — | XBRL Taxonomy Extension Definition Linkbase Document. | ||
101.LAB | (a) — | XBRL Taxonomy Extension Label Linkbase Document. | ||
101.PRE | (a) — | XBRL Taxonomy Extension Presentation Linkbase Document. |
(a) | Filed herewith. |
(b) | Furnished herewith. |
PIONEER NATURAL RESOURCES COMPANY | ||||
Date: November 5, 2012 | By: | /s/ RICHARD P. DEALY | ||
Richard P. Dealy | ||||
Executive Vice President and Chief Financial Officer | ||||
Date: November 5, 2012 | By: | /s/ FRANK W. HALL | ||
Frank W. Hall | ||||
Vice President and Chief Accounting Officer |
Exhibit Number | Description | |||
31.1 | (a) — | Chief Executive Officer certification under Section 302 of Sarbanes-Oxley Act of 2002. | ||
31.2 | (a) — | Chief Financial Officer certification under Section 302 of Sarbanes-Oxley Act of 2002. | ||
32.1 | (b) — | Chief Executive Officer certification under Section 906 of Sarbanes-Oxley Act of 2002. | ||
32.2 | (b) — | Chief Financial Officer certification under Section 906 of Sarbanes-Oxley Act of 2002. | ||
95.1 | (a) — | Mine Safety Disclosures | ||
101.INS | (a) — | XBRL Instance Document. | ||
101.SCH | (a) — | XBRL Taxonomy Extension Schema. | ||
101.CAL | (a) — | XBRL Taxonomy Extension Calculation Linkbase Document. | ||
101.DEF | (a) — | XBRL Taxonomy Extension Definition Linkbase Document. | ||
101.LAB | (a) — | XBRL Taxonomy Extension Label Linkbase Document. | ||
101.PRE | (a) — | XBRL Taxonomy Extension Presentation Linkbase Document. |
(a) | Filed herewith. |
(b) | Furnished herewith. |
1. | I have reviewed this quarterly report on Form 10-Q of Pioneer Natural Resources Company; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
/s/ Scott D. Sheffield |
Scott D. Sheffield, Chairman and |
Chief Executive Officer |
1. | I have reviewed this quarterly report on Form 10-Q of Pioneer Natural Resources Company; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
/s/ Richard P. Dealy |
Richard P. Dealy, Executive Vice President |
and Chief Financial Officer |
/s/ Scott D. Sheffield | ||
Name: | Scott D. Sheffield, Chairman and | |
Chief Executive Officer | ||
Date: | November 5, 2012 |
/s/ Richard P. Dealy | ||
Name: | Richard P. Dealy, Executive Vice | |
President and Chief Financial Officer | ||
Date: | November 5, 2012 |
Mine/MSHA Identification Number(1) | Section 104 S&S Citations | Section 104(b) Orders | Section 104(d) Citations and Orders | Section 110(b)(2) Violations | Section 107(a) Orders | Total Dollar Value of Proposed Assessments | Mining Related Fatalities | Received Notice of Pattern of Violations under Section 104(e) (yes/no) | Received Notice of Potential to have Pattern under Section 104(e) (yes/no) | Legal Actions Pending as of Last Day of Period | Legal Actions Initiated During Period | Legal Actions Resolved During Period | |||||||||||||||||||||||
Orange County Operation / 0402801 | 2 | — | — | — | — | $ | 4,825 | — | No | No | — | — | — | ||||||||||||||||||||||
Riverside Operation / 0404263 | — | — | — | — | — | $ | — | — | No | No | — | — | — | ||||||||||||||||||||||
Colorado Springs Operation / 0503295 | — | — | — | — | — | $ | — | — | No | No | — | — | — | ||||||||||||||||||||||
Glass Rock Operation / 3301354 | 1 | — | — | — | 1 | $ | 2,113 | — | No | No | — | — | — | ||||||||||||||||||||||
Millwood Operation / 3301355 | — | — | — | — | — | $ | — | — | No | No | — | — | — | ||||||||||||||||||||||
Voca Pit and Plant / 4101003 | 1 | — | — | — | — | $ | 951 | — | No | No | — | — | — | ||||||||||||||||||||||
Brady Plant / 4101371 | 3 | — | — | — | — | $ | 2,542 | — | No | No | — | — | — | ||||||||||||||||||||||
Voca West / 4103618 | — | — | — | — | — | $ | — | — | No | No | — | — | — |
(1 | ) | The definition of mine under section three of the Mine Act includes the mine, as well as other items used in, or to be used in, or resulting from, the work of extracting minerals, such as land, structures, facilities, equipment, machines, tools and minerals preparation facilities. Unless otherwise indicated, any of these other items associated with a single mine have been aggregated in the totals for that mine. MSHA assigns an identification number to each mine and may or may not assign separate identification numbers to related facilities such as preparation facilities. |
Basis Of Presentation (Goodwill) (Details) (USD $)
In Thousands, unless otherwise specified |
Sep. 30, 2012
|
Dec. 31, 2011
|
---|---|---|
Goodwill [Line Items] | ||
Goodwill | $ 293,449 | $ 298,142 |
Barnett Shale Field [Member]
|
||
Goodwill [Line Items] | ||
Goodwill | $ 4,693 |
Derivative Financial Instruments (Schedule Of Derivative Obligations Under Terminated Hedge Arrangements) (Details) (USD $)
In Thousands, unless otherwise specified |
3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | |||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2012
|
Sep. 30, 2011
|
Sep. 30, 2012
|
Sep. 30, 2011
|
Sep. 30, 2012
Interest Rate Derivatives [Member]
Interest Expense [Member]
|
Sep. 30, 2011
Interest Rate Derivatives [Member]
Interest Expense [Member]
|
Sep. 30, 2012
Interest Rate Derivatives [Member]
Interest Expense [Member]
|
Sep. 30, 2011
Interest Rate Derivatives [Member]
Interest Expense [Member]
|
Sep. 30, 2012
Interest Rate Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2011
Interest Rate Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2012
Interest Rate Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2011
Interest Rate Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2012
Commodity Price Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2011
Commodity Price Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2012
Commodity Price Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2011
Commodity Price Derivatives [Member]
Derivative Gains, Net [Member]
|
Sep. 30, 2012
Commodity Price Derivatives [Member]
Oil And Gas revenue [Member]
|
Sep. 30, 2011
Commodity Price Derivatives [Member]
Oil And Gas revenue [Member]
|
Sep. 30, 2012
Commodity Price Derivatives [Member]
Oil And Gas revenue [Member]
|
Sep. 30, 2011
Commodity Price Derivatives [Member]
Oil And Gas revenue [Member]
|
Sep. 30, 2012
Not Designated as Hedging Instrument [Member]
|
Dec. 31, 2011
Not Designated as Hedging Instrument [Member]
|
Sep. 30, 2012
Not Designated as Hedging Instrument [Member]
Derivatives - Noncurrent [Member]
Interest Rate Derivatives [Member]
|
Sep. 30, 2012
Not Designated as Hedging Instrument [Member]
Derivatives - Noncurrent [Member]
Commodity Price Derivatives [Member]
|
Dec. 31, 2011
Not Designated as Hedging Instrument [Member]
Derivatives - Noncurrent [Member]
Commodity Price Derivatives [Member]
|
|||||||
Derivative [Line Items] | |||||||||||||||||||||||||||||||
Total derivatives, Asset | $ 343,050 | [1] | $ 506,177 | [1] | $ 0 | $ 108,819 | [1] | $ 257,368 | [1] | ||||||||||||||||||||||
Total derivatives, Liability | 58,880 | [1] | 132,078 | [1] | 11,534 | 24,201 | [1] | 47,689 | [1] | ||||||||||||||||||||||
Amount of Gain/(Loss) Reclassified from AOCI into Earnings | 0 | 8,224 | (4,855) | 24,418 | 0 | (71) | (1,699) | (209) | 0 | 8,295 | (3,156) | 24,627 | |||||||||||||||||||
Derivative gains (losses), net | $ (123,994) | $ 401,072 | $ 243,568 | $ 386,118 | $ (5,199) | $ (6,335) | $ (24,238) | $ 6,088 | $ (118,795) | $ 407,407 | $ 267,806 | $ 380,030 | |||||||||||||||||||
|
Income Taxes (Schedule Of Income Tax (Provisions) Benefits Attributable To Income From Continuing Operations) (Details) (USD $)
|
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2012
|
Sep. 30, 2011
|
Sep. 30, 2012
|
Sep. 30, 2011
|
|
Income Tax Disclosure [Abstract] | ||||
Current Income Tax Expense (Benefit) | $ 13,052,000 | $ (3,035,000) | $ (6,927,000) | $ (8,075,000) |
Deferred income tax (provision) benefit | (21,438,000) | (179,693,000) | (241,608,000) | (270,657,000) |
Income tax (provision) benefit | (8,386,000) | (182,728,000) | (248,535,000) | (278,732,000) |
U.S. federal | (119.00%) | 34.00% | 38.00% | 34.00% |
Income loss before income taxes, including noncontrolling interest | $ 7,000,000 | $ (533,900,000) |
Net Income (Loss) Per Share (Tables)
|
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2012
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Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reconciliation of earnings attributable to common stockholders, basic and diluted | The following tables reconcile the Company's net income (loss) attributable to common stockholders to basic net income (loss) attributable to common stockholders and diluted net income (loss) attributable to common stockholders for the three and nine months ended September 30, 2012 and 2011:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reconciliation Of Basic To Diluted Weighted Average Common Shares Outstanding | 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, 2012 and 2011:
____________________
|
Basis Of Presentation (Policies)
|
9 Months Ended |
---|---|
Sep. 30, 2012
|
|
Basis Of Presentation [Abstract] | |
Presentation | Presentation. In the opinion of management, the consolidated financial statements of the Company as of September 30, 2012 and for the three and nine months ended September 30, 2012 and 2011 include all adjustments and accruals, consisting only of normal recurring accrual adjustments, which are necessary for a fair presentation of the results for the interim periods. These interim results are not necessarily indicative of results for a full year. Certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles in the United States ("GAAP") have been condensed or omitted in this Report pursuant to the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2011. Certain reclassifications have been made to the 2011 financial statement and footnote amounts in order to conform to the 2012 presentation. On May 6, 2008, the Company recognized a noncash gain on the sale of common units of Pioneer Southwest Energy Partners L.P. ("Pioneer Southwest," a majority-owned and consolidated subsidiary) as a component of additional paid-in capital in stockholders' equity. In accordance with the Financial Accounting Standards Board ("FASB") Accounting Standards Codification (“ASC”) Topic 740 Income Taxes, deferred income taxes of $49.1 million should be recognized for the future tax effects arising from the noncash gain on the sale of the Pioneer Southwest common units, with a corresponding decrease to additional paid-in capital. The Company recorded the deferred income taxes associated with this transaction in June 2012. The effect of this adjustment is immaterial to the accompanying financial statements. |
Derivatives And Hedging | Derivatives and hedging. All derivatives are recorded in the accompanying consolidated balance sheets at their estimated fair values. See Note E for information about the fair value of the Company's derivatives. Effective February 1, 2009, the Company discontinued hedge accounting on all of its then-existing derivative hedge contracts. Changes in the fair value of effective cash flow hedges prior to the Company's discontinuance of hedge accounting were recorded as a component of accumulated other comprehensive income or loss ("AOCI - Hedging"), in the equity section of the Company's consolidated balance sheets, and were transferred to earnings during the same periods in which the hedged transactions were recognized in the Company's earnings. During the six months ended June 30, 2012, the remaining hedge gains or losses that were previously deferred in AOCI - Hedging were transferred to earnings. Since discontinuing hedge accounting, the Company has recognized all changes in the fair values of its derivative contracts as gains or losses in the earnings of the periods in which they occur. The Company classifies the fair value amounts of derivative assets and liabilities executed under master netting arrangements as net current or noncurrent derivative assets or net current or noncurrent derivative liabilities, whichever the case may be, by commodity and counterparty. Net derivative asset values are determined, in part, by utilization of the derivative counterparties' credit-adjusted risk-free rate curves and net derivative liabilities are determined, in part, by utilization of the Company's and Pioneer Southwest's credit-adjusted risk-free rate curves. The credit-adjusted risk-free rate curves for the Company and its counterparties are generally based on their independent market-quoted credit default swap rate curves plus the United States Treasury Bill yield curve as of the valuation date. Pioneer Southwest's credit-adjusted risk-free rate curve is based on independent market-quoted forward London Interbank Offered Rate ("LIBOR") curves plus 162.5 basis points, representing Pioneer Southwest's borrowing rate. |
Goodwill | Goodwill. Goodwill is assessed for impairment whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely, but no less often than annually. If the carrying value of goodwill is determined to be impaired, it is reduced for the impaired value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired. During the third quarter of 2012, the Company performed a qualitative assessment of goodwill in accordance with FASB Accounting Standards Update ("ASU") No. 2011-08, Intangibles - Goodwill and Other (Topic 350) ("ASU 2011-08"), which permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test, and determined that it was not likely that the Company's goodwill was impaired. During the third quarter of 2012, the Company classified its Barnett Shale field assets and liabilities as discontinued operations held for sale. Associated therewith, the Company reclassified $4.7 million of goodwill attributable to the Barnett Shale assets to discontinued operations held for sale on the accompanying consolidated balance sheet at September 30, 2012. |
Impairment Of Long-Lived Assets | Impairment of assets. The Company reviews its long-lived assets for impairment, including oil and gas properties, whenever events or circumstances indicate that their carrying values may not be fully recoverable. If the carrying value of long-lived assets is determined to be impaired, it is reduced to its estimated fair value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired. See Note O for additional information about the Company's recent impairments and its risk of future impairments. |
Derivative Financial Instruments (Narrative) (Details) (USD $)
In Millions, unless otherwise specified |
1 Months Ended | 9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Apr. 30, 2012
|
Nov. 05, 2012
2012 Swap Contracts [Member]
|
Sep. 30, 2012
Rollfactor Swap Contracts [Member]
|
Nov. 05, 2012
Oil contracts [Member]
Two Thousand Thirteen Swap Contracts [Member]
bbl
|
Sep. 30, 2012
Oil contracts [Member]
Two Thousand Thirteen Swap Contracts [Member]
bbl
|
Sep. 30, 2012
Oil contracts [Member]
2012 Swap Contracts [Member]
bbl
|
Nov. 05, 2012
Oil contracts [Member]
2014 - Collar Contracts With Short Puts [Member]
bbl
|
Sep. 30, 2012
Oil contracts [Member]
2014 - Collar Contracts With Short Puts [Member]
bbl
|
Sep. 30, 2012
Oil contracts [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
bbl
|
Sep. 30, 2012
Oil contracts [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
bbl
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
Two Thousand Thirteen Swap Contracts [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
2012 Swap Contracts [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
2014 - Collar Contracts With Short Puts [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
2014 - Collar Contracts With Short Puts [Member]
Short Put [Member]
|
Nov. 05, 2012
Oil contracts, price per bbl [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
|
Nov. 05, 2012
Oil contracts, price per bbl [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
Short Put [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
Short Put [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
|
Sep. 30, 2012
Oil contracts, price per bbl [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
Short Put [Member]
|
Sep. 30, 2012
NGL contract, in BBLS [Member]
Two Thousand Thirteen Swap Contracts [Member]
bbl
|
Sep. 30, 2012
NGL contract, in BBLS [Member]
2012 Swap Contracts [Member]
bbl
|
Sep. 30, 2012
NGL contract, in BBLS [Member]
2014 - Collar Contracts With Short Puts [Member]
bbl
|
Nov. 05, 2012
NGL contract, in BBLS [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
bbl
|
Sep. 30, 2012
NGL contract, in BBLS [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
bbl
|
Nov. 05, 2012
Natural gasoline contract, in barrels [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
bbl
|
Nov. 05, 2012
Gas contracts, in MMBTU [Member]
Two Thousand Thirteen Swap Contracts [Member]
MMBTU
|
Sep. 30, 2012
Gas contracts, in MMBTU [Member]
Two Thousand Thirteen Swap Contracts [Member]
MMBTU
|
Sep. 30, 2012
Gas contracts, in MMBTU [Member]
2012 Swap Contracts [Member]
MMBTU
|
Sep. 30, 2012
Gas contracts, in MMBTU [Member]
2014 - Collar Contracts With Short Puts [Member]
MMBTU
|
Sep. 30, 2012
Gas contracts, in MMBTU [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
MMBTU
|
Nov. 05, 2012
Gas contracts, in MMBTU [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
MMBTU
|
Sep. 30, 2012
Gas contracts, in MMBTU [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
MMBTU
|
Nov. 05, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Thirteen Swap Contracts [Member]
|
Sep. 30, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Thirteen Swap Contracts [Member]
|
Nov. 05, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Thirteen Swap Contracts [Member]
Short Put [Member]
|
Sep. 30, 2012
Gas contracts, price per MMBTU [Member]
2012 Swap Contracts [Member]
|
Sep. 30, 2012
Gas contracts, price per MMBTU [Member]
2014 - Collar Contracts With Short Puts [Member]
|
Sep. 30, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Thirteen Collar Contracts With Short Puts [Member]
|
Nov. 05, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
|
Sep. 30, 2012
Gas contracts, price per MMBTU [Member]
Two Thousand Fifteen Collar Contracts With Short Puts [Member]
|
|||||||||||
Schedule of Trading Securities and Other Trading Assets [Line Items] | |||||||||||||||||||||||||||||||||||||||||||||||||||
Average Daily NGL Production Derivative Barrels Per Day | 0 | 2,750 | 1,000 | 1,000 | 1,000 | 1,064 | |||||||||||||||||||||||||||||||||||||||||||||
Average daily oil production derivative barrels per day | 17,000 | 20,000 | [1] | 11,000 | [1] | 17,000 | 60,000 | 54,029 | 26,000 | ||||||||||||||||||||||||||||||||||||||||||
Nonmonetary Notional Amount of Price Risk Derivative Instruments Not Designated as Hedging Instruments | 3.00 | [2] | |||||||||||||||||||||||||||||||||||||||||||||||||
Derivative, Swap Type, Fixed Price | 100.14 | 97.27 | 89.34 | 4.01 | 5.62 | 4.97 | |||||||||||||||||||||||||||||||||||||||||||||
NYMEX swap multiple, second nearby month | 0.6667 | ||||||||||||||||||||||||||||||||||||||||||||||||||
NYMEX swap multiple, third nearby month | 0.3333 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative, Average Cap Price (per BBL) | 117.06 | 120.29 | 119.60 | 104.45 | 0.00 | [2] | 0.00 | 5.35 | [2] | 4.97 | [2] | ||||||||||||||||||||||||||||||||||||||||
Derivative, Average Floor Price (per BBL) | 92.67 | 100.41 | 89.71 | 95.00 | 0.00 | [2] | 0.00 | 4.00 | [2] | 4.00 | [2] | ||||||||||||||||||||||||||||||||||||||||
Derivative, Nonmonetary Notional Amount, Price Per Unit | 76.58 | 75.99 | 73.74 | 80.00 | |||||||||||||||||||||||||||||||||||||||||||||||
Derivative, Fixed Interest Rate | 3.21% | ||||||||||||||||||||||||||||||||||||||||||||||||||
Notional amount of debt | $ 250 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Average Daily Gas Production Derivatives Volume (MMBTU) | 50,000 | 112,500 | 275,000 | 0 | 0 | 70,000 | 155,000 | ||||||||||||||||||||||||||||||||||||||||||||
|
Acquisitions and Divestitures Acquisitions and Divestitures (Components Of Discontinued Operations) (Details) (USD $)
In Thousands, unless otherwise specified |
3 Months Ended | 9 Months Ended | ||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2012
|
Sep. 30, 2011
|
Sep. 30, 2012
|
Sep. 30, 2011
|
|||||||||
Acquisitions and Divestitures [Abstract] | ||||||||||||
Oil and gas | $ 30,466 | $ 36,395 | $ 111,426 | $ 118,137 | ||||||||
Interest and other | 0 | 224 | 20 | 5,195 | ||||||||
Gain (loss) on disposition of assets, net | 28,179 | [1] | (58) | [1] | 28,157 | [1] | 645,241 | [1] | ||||
Total revenues and other income from discontinued operations | 58,645 | 36,561 | 139,603 | 768,573 | ||||||||
Oil and gas production | 11,573 | 6,944 | 35,718 | 19,023 | ||||||||
Production and ad valorem taxes | 744 | 829 | 2,273 | 1,720 | ||||||||
Depletion, depreciation and amortization | 3,134 | [1] | 18,043 | [1] | 32,673 | [1] | 54,717 | [1] | ||||
Impairment of oil and gas properties | 0 | [1],[2] | 0 | [1],[2] | 444,880 | [1],[2] | 0 | [1],[2] | ||||
Exploration and abandonments | 372 | 6,005 | 8,660 | 19,021 | ||||||||
General and administrative | 721 | 471 | 1,853 | 9,868 | ||||||||
Accretion of discount on asset retirement obligations | 344 | [1] | 813 | [1] | 1,898 | [1] | 2,270 | [1] | ||||
Interest | 0 | 0 | (75) | 773 | ||||||||
Other | (26) | 245 | 1,313 | 4,457 | ||||||||
Total costs and expenses from discontinued operations | 16,862 | 33,350 | 529,193 | 111,849 | ||||||||
Income from discontinued operations before income taxes | 41,783 | 3,211 | (389,590) | 656,724 | ||||||||
Current tax provision | (4,231) | (9,338) | (8,317) | (35,872) | ||||||||
Deferred tax provision | (2,902) | [1] | 6,457 | [1] | 157,433 | [1] | (210,296) | [1] | ||||
Income from discontinued operations | $ 34,650 | $ 330 | $ (240,474) | $ 410,556 | ||||||||
|
Basis Of Presentation Basis of Presentation (Revision for Deferred Income Taxes) (Details) (Restatement Adjustment [Member], USD $)
In Millions, unless otherwise specified |
12 Months Ended |
---|---|
Dec. 31, 2011
|
|
Decrease in Current Deferred Tax Assets, Revision of Unrealized Current Derivative Gains, Net [Member]
|
|
Adjustment to deferred income taxes due to revision of unrealized current derivative gains, net | $ 77.0 |
Increase in Current Deferred Tax Liabilities, Revision of Unrealized Current Derivative Gains, Net [Member]
|
|
Adjustment to deferred income taxes due to revision of unrealized current derivative gains, net | 57.7 |
Decrease in Noncurrent Deferred Tax Liabilities, Revision of Unrealized Current Derivative Gains, Net [Member]
|
|
Adjustment to deferred income taxes due to revision of unrealized current derivative gains, net | $ 134.7 |
Derivative Financial Instruments (Schedule Of Marketing And Basis Transfer Derivative Contracts) (Details)
|
Sep. 30, 2012
MMBTU
|
---|---|
Two Thousand Twelve Fourth Quarter Index Basis Swap Contracts [Member] | Basic Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | 43,370 |
Price Differential | 0.24 |
Two Thousand And Thirteen Index Basis Swap Contracts [Member] | Basic Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | 9,863 |
Price Differential | 0.25 |
Two Thousand Twelve Fourth Quarter Short Index Basis Swap Contracts [Member] [Member] | Basic Short Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | 1,685 |
NGI-So Cal Border Monthly price differential to NYMEX HH | 0.12 |
Two Thousand Thirteen Short Index Basis Swap Contracts | Basic Short Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | 0 |
NGI-So Cal Border Monthly price differential to NYMEX HH | 0.00 |
Two Thousand Twelve Fourth Quarter Long Index Basis Swap Contracts [Member] [Member] [Member] | Basic Long Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | (1,685) |
NGI-So Cal Border Monthly price differential to NYMEX HH | (0.05) |
Two Thousand Thirteen Long Index Basis Swap Contracts [Member] | Basic Long Index Swaps [Member]
|
|
Derivative [Line Items] | |
Average Daily Index Swaps Volume | 0 |
NGI-So Cal Border Monthly price differential to NYMEX HH | 0.00 |
Other Expense (Schedule Of Components Of Other Expense) (Details) (USD $)
In Thousands, unless otherwise specified |
3 Months Ended | 9 Months Ended | ||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2012
|
Sep. 30, 2011
|
Sep. 30, 2012
|
Sep. 30, 2011
|
|||||||||
Other Expense [Abstract] | ||||||||||||
Transportation commitment charges | $ 9,694 | [1] | $ 5,141 | [1] | $ 27,374 | [1] | $ 16,101 | [1] | ||||
Above market drilling rig rates | 12,720 | [1] | 4,632 | [1] | 23,466 | [1] | 15,201 | [1] | ||||
Terminated drilling rig contract charges | 6,807 | [2] | 0 | [2] | 15,768 | [2] | 0 | [2] | ||||
Inventory valuation charges | 46 | [2] | 1,745 | [2] | 6,093 | [2] | 2,332 | [2] | ||||
Other | 2,340 | 4,951 | 10,136 | 9,867 | ||||||||
Premier Silica acquisition costs | 246 | 0 | 2,419 | 0 | ||||||||
Contingency and environmental accrual adjustments | 70 | 588 | 772 | 3,470 | ||||||||
Loss on extinguishment of debt | ||||||||||||
Total other expense | $ 31,923 | $ 17,057 | $ 86,028 | $ 46,971 | ||||||||
|
Fair Value Measurements (Schedule Of Carrying Values And Financial Instruments Not Carried At Fair Value) (Details) (USD $)
In Thousands, unless otherwise specified |
Sep. 30, 2012
|
Dec. 31, 2011
|
---|---|---|
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Long-term Debt Element | $ 3,562,070 | $ 2,528,905 |
Carrying Value [Member]
|
||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Long-term Debt Element | 3,562,070 | 2,528,905 |
Fair Value [Member]
|
||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Long-term Debt Element | $ 4,449,088 | $ 3,105,585 |
Organization And Nature Of Operations
|
9 Months Ended |
---|---|
Sep. 30, 2012
|
|
Organization And Nature Of Operations [Abstract] | |
Organization And Nature Of Operations | Organization and Nature of Operations Pioneer Natural Resources Company ("Pioneer" or the "Company") is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. The Company is a large independent oil and gas exploration and production company with operations in the United States. |
Impairment (Details) (USD $)
|
3 Months Ended | 9 Months Ended | 12 Months Ended | |||
---|---|---|---|---|---|---|
Sep. 30, 2012
|
Jun. 30, 2012
Rate
|
Sep. 30, 2011
|
Sep. 30, 2012
|
Sep. 30, 2011
|
Dec. 31, 2011
|
|
Impairment [Abstract] | ||||||
Pretax noncash impairment charges | $ 0 | $ 444,900,000 | $ 0 | $ 0 | $ 0 | $ 354,400,000 |
Management oil price outlook (BBL) | 87.09 | |||||
Management gas price outlook (MCF) | 4.64 | |||||
Discount rate used in impairment calculation | 10.00% | |||||
Raton Shale Field [Member]
|
||||||
Impaired Long-Lived Assets Held and Used [Line Items] | ||||||
Carrying value of asset group | $ 2,200,000,000 | $ 2,200,000,000 |