Pioneer Natural Resources (PXD) 10-Q 3 Nov 15 2015 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 30, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Trading Symbol	PXD
Entity Registrant Name	PIONEER NATURAL RESOURCES CO
Entity Central Index Key	1,038,357
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		149,377,919

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 581	$ 1,025
Accounts receivable:
Trade, net	413	436
Due from affiliates	0	4
Income taxes receivable	0	23
Inventories	238	241
Prepaid expenses	19	15
Other current assets:
Notes receivable	497	0
Derivatives Assets, Current	632	578
Other	23	37
Total current assets	2,403	2,359
Oil and gas properties, using the successful efforts method of accounting:
Proved properties	16,799	15,662
Unproved properties	170	159
Accumulated depletion, depreciation and amortization	(6,407)	(5,431)
Total property, plant and equipment	10,562	10,390
Goodwill	272	272
Property, Plant and Equipment, Net	1,480	1,391
Other assets:
Investment in unconsolidated affiliate	0	239
Derivative Assets, Noncurrent	147	181
Other, net	101	94
Assets, Total	14,965	14,926
Accounts payable:
Trade	791	1,197
Due to affiliates	58	123
Interest payable	36	40
Income taxes payable	27	1
Deferred Tax Liabilities, Net, Current	172	161
Other current liabilities:
Derivative Liabilities, Current	2	3
Other	61	55
Total current liabilities	1,147	1,580
Long-term Debt, Excluding Current Maturities	2,675	2,665
Derivative Liabilities, Noncurrent	1	2
Deferred income taxes	1,925	1,803
Other liabilities	236	287
Stockholders' equity:
Common stock, $.01 par value	2	2
Additional paid-in capital	6,250	6,167
Treasury stock at cost	(199)	(171)
Retained earnings	2,921	2,583
Total equity attributable to common stockholders	8,974	8,581
Noncontrolling interests in consolidating subsidiaries	7	8
Total equity	$ 8,981	$ 8,589
Commitments and contingencies
Liabilities and Stockholders' Equity, Total	$ 14,965	$ 14,926

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	152,774,139	152,158,428
Treasury Stock, Shares	3,396,220	3,253,781

Consolidated Statements Of Oper

Consolidated Statements Of Operations - USD ($) $ in Thousands, shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues and other income:
Oil and gas	$ 557,000	$ 967,000	$ 1,670,000	$ 2,795,000
Sales of purchased oil and gas	326,000	202,000	665,000	554,000
Interest and other	(17,000)	2,000	0	9,000
Derivative gains, net	573,000	341,000	617,000	19,000
Gain (loss) on disposition of assets, net	779,000	1,000	782,000	11,000
Total revenues and other income	2,218,000	1,513,000	3,734,000	3,388,000
Costs and expenses:
Oil and gas production	189,000	168,000	532,000	493,000
Production and ad valorem taxes	36,000	58,000	112,000	169,000
Depletion, depreciation and amortization	364,000	274,000	1,003,000	734,000
Purchased oil and gas	339,000	194,000	684,000	535,000
Impairment of oil and gas properties	72,000	0	210,000	0
Exploration and abandonments	25,000	22,000	79,000	80,000
General and administrative	81,000	81,000	246,000	244,000
Accretion of discount on asset retirement obligations	3,000	3,000	9,000	9,000
Interest	46,000	46,000	138,000	138,000
Other	60,000	20,000	170,000	55,000
Costs and Expenses	1,215,000	866,000	3,183,000	2,457,000
Income from continuing operations before income taxes	1,003,000	647,000	551,000	931,000
Income tax provision	(355,000)	(236,000)	(195,000)	(319,000)
Income from continuing operations	648,000	411,000	356,000	612,000
Loss from discontinued operations, net of tax	(2,000)	(37,000)	(6,000)	(113,000)
Net income			350,000	499,000
Net income (loss) attributable to common stockholders	$ 646,000	$ 374,000	$ 350,000	$ 499,000
Basic earnings per share:
Income from continuing operations	$ 4.29	$ 2.84	$ 2.36	$ 4.24
Loss from discontinued operations	(0.01)	(0.26)	(0.04)	(0.79)
Net income	4.28	2.58	2.32	3.45
Diluted earnings per share:
Income from continuing operations	4.28	2.84	2.36	4.23
Loss from discontinued operations	(0.01)	(0.26)	(0.04)	(0.79)
Net income	$ 4.27	$ 2.58	$ 2.32	$ 3.44
Weighted average shares outstanding:
Basic	149	143	149	143
Diluted	150	143	149	143
Dividends declared per share	$ 0.04	$ 0.04	$ 0.08	$ 0.08
Amounts attributable to common stockholders:
Net income (loss) attributable to common stockholders	$ 646,000	$ 374,000	$ 350,000	$ 499,000

Consolidated Statement Of Equit

Consolidated Statement Of Equity - 9 months ended Sep. 30, 2015 - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Noncontrolling Interests [Member]
Beginning Balance, shares at Dec. 31, 2014		149,000
Beginning Balance at Dec. 31, 2014	$ 8,589,000	$ 2,000	$ 6,167,000	$ (171,000)	$ 2,583,000	$ 8,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared ($0.08 per share)	(12,000)				(12,000)
Exercise of long-term incentive plan stock options and employee stock purchases, shares		0
Exercise of long-term incentive plan stock options and employee stock purchases	6,000		3,000	3,000
Treasury stock purchases, shares		0
Treasury stock purchases	(31,000)			(31,000)
Tax benefit related to stock-based compensation	10,000		10,000
Compensation costs:
Vested compensation awards, net, shares		616
Vested compensation awards, net	0	$ 6	(6)
Compensation costs included in net income	70,000		70,000			0
Cash distributions to noncontrolling interests	(1,000)					(1,000)
Net loss	350,000				350,000	0
Ending Balance, shares at Sep. 30, 2015		149,000
Ending Balance at Sep. 30, 2015	$ 8,981,000	$ 2,000	$ 6,250,000	$ (199,000)	$ 2,921,000	$ 7,000

Consolidated Statement Of Equi6

Consolidated Statement Of Equity (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Stockholders' Equity [Abstract]
Dividends declared per share	$ 0.04	$ 0.04	$ 0.08	$ 0.08

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities:
Net income (loss)	$ 350,000	$ 499,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation and amortization	1,003,000	734,000
Impairment of oil and gas properties	210,000	0
Impairment of Inventory and Other Property and Equipment	21,000	7,000
Exploration expenses, including dry holes	22,000	11,000
Deferred income taxes	146,000	315,000
Gain on disposition of assets, net	(782,000)	(11,000)
Accretion of discount on asset retirement obligations	9,000	9,000
Discontinued operations	(4,000)	247,000
Interest expense	14,000	13,000
Derivative related activity	(22,000)	(39,000)
Amortization of stock-based compensation	70,000	63,000
Other	13,000	42,000
Change in operating assets and liabilities, net of effects from acquisitions and dispositions:
Accounts receivable, net	26,000	(77,000)
Income taxes receivable	23,000	(17,000)
Inventories	(29,000)	(27,000)
Prepaid expenses	(3,000)	(11,000)
Other current assets	(6,000)	(1,000)
Accounts payable	(266,000)	96,000
Interest payable	(4,000)	(26,000)
Income taxes payable	26,000	1,000
Other current liabilities	(28,000)	(30,000)
Net cash provided by operating activities	789,000	1,798,000
Cash flows from investing activities:
Proceeds from disposition of assets, net of cash sold	556,000	855,000
Additions to oil and gas properties	(1,573,000)	(2,259,000)
Additions to other assets and other property and equipment, net	(191,000)	(224,000)
Net cash used in investing activities	(1,208,000)	(1,628,000)
Cash flows from financing activities:
Borrowings under long-term debt	0	523,000
Principal payments on long-term debt	0	(523,000)
Distributions to noncontrolling interests	(1,000)	(1,000)
Exercise of long-term incentive plan stock options and employee stock purchases	6,000	13,000
Purchases of treasury stock	(31,000)	(33,000)
Tax benefits related to stock-based compensation	10,000	14,000
Payments of financing fees	(3,000)	0
Dividends paid	(6,000)	(6,000)
Net cash used in financing activities	(25,000)	(13,000)
Net increase (decrease) in cash and cash equivalents	(444,000)	157,000
Cash and cash equivalents, beginning of period	1,025,000	393,000
Cash and cash equivalents, end of period	$ 581,000	$ 550,000

Organization And Nature Of Oper

Organization And Nature Of Operations	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [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 operating in the United States, with operations primarily in the Permian Basin in West Texas, the Eagle Ford Shale play in South Texas, the Raton field in southeastern Colorado and the West Panhandle field in the Texas Panhandle.

Basis Of Presentation

Basis Of Presentation	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis Of Presentation	Basis of Presentation Presentation. In the opinion of management, the consolidated financial statements of the Company as of September 30, 2015 and for the three and nine months ended September 30, 2015 and 2014 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 in or omitted from 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, 2014 . Certain reclassifications have been made to the 2014 financial statement and footnote amounts in order to conform to the 2015 presentation. Restructuring. On May 4, 2015, the Company announced plans to restructure its operations in Colorado, including closing its office in Denver, Colorado and eliminating its Trinidad-based pumping services operations. In connection therewith, during the three and nine months ended September 30, 2015, the Company recognized $9 million and $24 million , respectively, of restructuring charges in other expense in the accompanying consolidated statements of operations. The Company estimates that it will incur an additional $3 million of restructuring charges during the fourth quarter of 2015. The aggregate $27 million of estimated restructuring charges includes approximately $18 million in employee severance costs, $6 million in lease-related costs and $3 million in employee relocation and other costs. Employee severance costs. The $18 million of employee severance costs is based on the number of employees impacted by the restructuring. Approximately $17 million is related to cash severance and $1 million is related to accelerated vesting of share-based grants, which are noncash charges. Lease obligations and other . The $6 million of lease-related costs relates to certain Denver office space that will no longer be used as a part of the restructuring. Approximately $2 million represents the impairment of leasehold improvements and approximately $4 million represents the Company’s future obligations under the operating leases, net of anticipated sublease income. As of September 30, 2015, the Company had $4 million of restructuring liabilities related to employee severance costs and future lease obligations recorded in other current and noncurrent liabilities in the accompanying consolidated balance sheets. New accounting pronouncements. In July 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory." ASU 2015-11 requires an entity to measure inventory at the lower of cost or net realizable value rather than lower of cost or market as previously required by GAAP. ASU 2015-11 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. This update should be applied prospectively with early application permitted. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements. In April 2015, the FASB issued ASU 2015-03, "Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs." ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Currently, debt issuance costs are recognized as deferred charges and recorded as assets. The guidance is effective for annual and interim periods beginning after December 15, 2015 with early adoption permitted and is to be implemented retrospectively. Adoption of the new guidance will only affect the presentation of the Company's consolidated balance sheets and will not have a material impact. In May 2014, the FASB issued ASU 2014-09, "Revenue from Contracts with Customers (Topic 606)," which supersedes the revenue recognition requirements in Accounting Standards Codification ("ASC") Topic 605, "Revenue Recognition," and most industry-specific guidance. ASU 2014-09 is based on the principle that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU 2015-14, which defers the effective date of ASU 2014-09 for one year to annual reports beginning after December 15, 2017. Early adoption is permitted as of the original effective date, December 15, 2016. Entities have the option of using either a full retrospective or modified approach to adopt the new standards. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.

Acquisitions and Divestitures

Acquisitions and Divestitures	9 Months Ended
	Sep. 30, 2015
Acquisitions and Divestitures [Abstract]
Acquisition and Divestitures	Divestitures Divestitures Recorded in Continuing Operations For the three and nine months ended September 30, 2015 , the Company recorded net gains on disposition of assets in continuing operations of $779 million and $782 million , respectively, as compared to $1 million and $11 million for the same respective periods in 2014 . The net gains attributable to the disposition of assets included the following: • EFS Midstream. In November 2014, the Company announced that it was pursuing the divestment of its 50.1 percent equity interest in EFS Midstream LLC ("EFS Midstream"), which was accounted for under the equity method of accounting for investments in unconsolidated affiliates. In July 2015, the Company closed on the sale of its interest in EFS Midstream to an unaffiliated third party, with the Company receiving total consideration of $1.0 billion , of which $530 million was received at closing and the remaining approximately $500 million will be received in July 2016. The amount to be received in July 2016, less imputed interest, is included in notes receivable in the accompanying consolidated balance sheets and represents a noncash investing activity. Associated with the sale, the Company recorded a pretax gain of $778 million during the third quarter of 2015. • Vertical drilling rigs . In March 2014, the Company completed the sale of Sendero Drilling Company, LLC ("Sendero") to Sendero's minority interest owner for cash proceeds of $31 million , which resulted in a gain of $1 million . As part of the sales agreement, the Company committed to a lease agreement with Sendero for 12 vertical rigs through December 31, 2015, and eight vertical rigs in 2016. During the three and nine months ended September 30, 2015 , the Company incurred $10 million and $30 million of idle drilling rig fees related to the leased Sendero rigs. • Permian Basin. During February 2014, the Company completed the sale of proved and unproved properties in Gaines and Dawson counties in the Spraberry field in West Texas for cash proceeds of $72 million , which resulted in a gain of $2 million . Divestitures Recorded as Discontinued Operations During 2014, the Company completed the sales of its (i) net assets in the Hugoton field in southwest Kansas for cash proceeds of $328 million , (ii) net assets in the Barnett Shale field in North Texas for cash proceeds of $150 million and (iii) capital stock in its Alaskan subsidiary ("Pioneer Alaska") for cash proceeds of $267 million . The Company has included its Hugoton, Barnett Shale and Pioneer Alaska results of operations in loss from discontinued operations, net of tax, in the accompanying consolidated statements of operations. The following table represents the components of the Company's discontinued operations for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Revenues and other income (a) $ — $ 50 $ 1 $ 234 Costs and expenses (b) (2 ) (108 ) (10 ) (408 ) Loss from discontinued operations before income taxes (2 ) (58 ) (9 ) (174 ) Current tax provision — — — (1 ) Deferred tax benefit — 21 3 62 Loss from discontinued operations, net of tax $ (2 ) $ (37 ) $ (6 ) $ (113 ) ____________________ (a) Primarily reflects oil and gas revenues and cash received associated with Alaskan Petroleum Production Tax credits on qualifying capital expenditures. (b) Costs and expenses during 2015 were primarily related to an arbitration award associated with plugging and abandonment obligations for two Gulf of Mexico wells from which Pioneer withdrew in 2009. Costs and expenses in 2014 were primarily comprised of oil and gas production costs and impairment charges. See Note D for information about impairment charges on the Barnett Shale assets and Pioneer Alaska.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or the price paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The three input levels of the fair value hierarchy are as follows: • 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. Assets and liabilities measured at fair value on a recurring basis. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety. The following table presents the Company's assets and liabilities that are measured at fair value on a recurring basis as of September 30, 2015 for each of the fair value hierarchy levels: Fair Value Measurement at September 30, 2015 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, 2015 (in millions) Assets: Commodity derivatives $ — $ 779 $ — $ 779 Deferred compensation plan assets 69 — — 69 Total assets 69 779 — 848 Liabilities: Commodity derivatives — 1 — 1 Interest rate derivatives — 2 — 2 Total liabilities — 3 — 3 Total recurring fair value measurements $ 69 $ 776 $ — $ 845 Commodity derivatives. The Company's commodity derivatives represent oil, natural gas liquids ("NGL") and gas swap contracts and collar contracts with short puts. The asset and liability measurements for the Company's commodity derivative contracts represent Level 2 inputs in the hierarchy. The Company utilizes discounted cash flow and option-pricing models for valuing its commodity derivatives. The asset and liability values attributable to the Company's commodity derivatives were determined based on inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated credit-adjusted risk-free rate yield curve and (iv) the implied rate of volatility inherent in the collar contracts with short puts, which is based on active and independent market-quoted volatility factors. Deferred compensation plan assets. The Company's deferred compensation plan assets represent investments in equity and mutual fund securities that are actively traded on major exchanges. These investments are measured based on observable prices on major exchanges. As of September 30, 2015 , the significant inputs to these asset values represented Level 1 independent active exchange market price inputs. Interest rate derivatives. The Company's interest rate derivative liabilities represent Treasury rate swap contracts and interest rate swap contracts. The Company utilizes discounted cash flow models for valuing its interest rate derivatives. The net derivative values attributable to the Company's interest rate derivative contracts are based on (i) the contracted notional amounts, (ii) forward active market-quoted London Interbank Offered Rate ("LIBOR") or United States Treasury yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve. The Company's interest rate derivative fair value measurements represent Level 2 inputs in the hierarchy. Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances. These assets and liabilities can include inventory, proved and unproved oil and gas properties and other long-lived assets that are written down to fair value when they are impaired or held for sale. During the three and nine months ended September 30, 2015 , the Company recorded charges in other expense in the Company's accompanying consolidated statements of operations of $12 million and $20 million , respectively, to reduce the carrying value of inventory to fair value. Proved oil and gas properties . During 2015, reductions in management's longer-term commodity price outlooks ("Management's Price Outlooks") provided indications of possible impairment of the Company's oil and gas properties in the West Panhandle field and in the South Texas - Other field (Edwards dry gas). As a result of management's assessments, during March 2015 and September 2015, the Company recognized pretax noncash impairment charges to reduce the carrying values of the West Panhandle field and the South Texas - Other field, respectively, to their estimated fair values. The Company calculated the fair values of the West Panhandle field and the South Texas - Other field using a discounted future cash flow model. Significant Level 3 assumptions associated with the calculations included Management's Price Outlooks and management's outlooks for (i) production costs, (ii) capital expenditures, (iii) production and (iv) estimated proved reserves and risk-adjusted probable reserves. Management's Price Outlooks are developed based on third-party futures price outlooks as of the measurement date. The expected future net cash flows were discounted using an annual rate of 10 percent to determine estimated fair value. The following table presents the fair value and fair value adjustments (in millions) for the Company's March 2015 and September 2015 proved property impairments, as well as the average oil price per barrel ("Bbl") and gas price per British thermal unit ("MMBtu") utilized in respective Management's Price Outlooks: Management's Price Outlooks Fair Value Fair Value Adjustment Oil Gas West Panhandle March 2015 $ 61 $ (138 ) $ 65.02 $ 3.83 South Texas - Other September 2015 $ 88 $ (72 ) $ 57.41 $ 3.46 Assets associated with divestitures. Long-lived assets that are classified as held for sale are recorded at the lower of the asset's net carrying amount or estimated fair value less costs to sell. The Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska were classified as held for sale and carried as such until their divestitures in September 2014, September 2014 and April 2014, respectively. Associated therewith, the Company recognized impairment charges during 2014 to reduce the carrying values of the Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska to their sales prices, less costs to sell. The following table presents the fair value adjustments made by the Company during 2014 related to assets associated with divestitures: Fair Value Adjustment Sales Value Less Costs to Sell Three Months Ended September 30, 2014 Nine Months Ended September 30, 2014 (in millions) Hugoton field $ 328 $ (34 ) $ (34 ) Barnett Shale field $ 149 $ (46 ) $ (174 ) Pioneer Alaska $ 253 $ — $ (97 ) See Note C for additional information regarding the Company's divestitures of the Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska. Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the accompanying consolidated balance sheets as of September 30, 2015 and December 31, 2014 are as follows: September 30, 2015 December 31, 2014 Carrying Value Fair Value Carrying Value Fair Value (in millions) Long-term debt $ 2,675 $ 2,867 $ 2,665 $ 2,938 Long-term debt includes the Company's credit facility and the Company's senior notes. The fair value of debt is determined utilizing inputs that are Level 2 measurements in the fair value hierarchy. Credit facility . The fair value of the Company's credit facility is calculated using a discounted cash flow model based on (i) forecasted contractual interest and fee payments, (ii) forward active market-quoted United States Treasury Bill rates and (iii) the applicable credit-adjustments. Senior notes . The Company's senior notes represent debt securities that are traded on major exchanges but are not actively traded. The fair values of the Company's senior notes are based on their periodic values as quoted on the major exchanges. The Company has other financial instruments consisting primarily of cash equivalents, accounts receivables, prepaid expenses, notes receivable, payables and other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities. Non-financial assets and liabilities initially measured at fair value include assets acquired and liabilities assumed in a business combination, goodwill and asset retirement obligations.

Derivative Financial Instrument

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments The Company utilizes commodity swap contracts, collar contracts and collar contracts with short puts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's annual capital budgeting and expenditure plans and (iii) reduce commodity price risk associated with certain capital projects. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness. Oil production derivative activities. All material physical sales contracts governing the Company's oil production are tied directly to, or are highly correlated with, New York Mercantile Exchange ("NYMEX") West Texas Intermediate ("WTI") oil prices. The Company uses derivative contracts to manage oil price volatility and basis swap contracts to reduce basis risk between NYMEX prices and the actual index prices at which the oil is sold. The following table sets forth the volumes per day associated with the Company's outstanding oil derivative contracts as of September 30, 2015 and the weighted average oil prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 2017 Swap contracts: Volume (Bbl) 82,000 4,475 — Price per Bbl $ 71.18 $ 59.00 $ — Collar contracts with short puts (a): Volume (Bbl) 15,000 101,806 34,000 Price per Bbl: Ceiling $ 97.69 $ 75.93 $ 70.42 Floor $ 82.97 $ 65.30 $ 57.65 Short put $ 69.67 $ 46.08 $ 47.65 Rollfactor swap contracts (b): Volume (Bbl) 37,000 — — NYMEX roll price $ 0.06 $ — $ — ____________________ (a) Counterparties have the option to extend for an additional year 5,000 Bbls per day of 2015 collar contracts with short puts with a ceiling price of $100.08 per Bbl, a floor price of $90.00 per Bbl and a short put price of $80.00 per Bbl. The option to extend is exercisable on December 31, 2015. These contracts give the counterparties the option to extend the contracts under the same terms for an additional year if the option to extend is exercised by the counterparties on December 31, 2015. (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 . NGL production derivative activities. All material physical sales contracts governing the Company's NGL production are tied directly or indirectly to either Mont Belvieu or Conway NGL component product prices. The following table sets forth the volumes per day associated with the Company's outstanding NGL derivative contracts as of September 30, 2015 and the weighted average NGL prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 Ethane swap contracts: Volume (Bbl) 6,000 5,000 Price per Bbl $ 7.80 $ 11.61 Propane swap contracts: Volume (Bbl) 11,000 7,500 Price per Bbl $ 21.62 $ 21.57 Gas production derivative activities. All material physical sales contracts governing the Company's gas production are tied directly or indirectly to NYMEX Henry Hub ("HH") gas prices or regional index prices where the gas is sold. The Company uses derivative contracts to manage gas price volatility and basis swap contracts to reduce basis risk between HH prices and the actual index prices at which the gas is sold. The following table sets forth the volumes per day associated with the Company's outstanding gas derivative contracts as of September 30, 2015 and the weighted average gas prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 2017 Swap contracts: Volume (MMBtu) 20,000 70,000 — Price per MMBtu $ 4.31 $ 4.06 $ — Collar contracts with short puts: Volume (MMBtu) 285,000 180,000 — Price per MMBtu: Ceiling $ 5.07 $ 4.01 $ — Floor $ 4.00 $ 3.24 $ — Short put $ 3.00 $ 2.78 $ — Basis swap contracts: Gulf Coast index swap volume (a) 20,000 10,000 — Price differential ($/MMBtu) $ — $ — $ — Mid-Continent index swap volume (a) 95,000 15,000 45,000 Price differential ($/MMBtu) $ (0.24 ) $ (0.32 ) $ (0.32 ) Permian Basin index swap volume (a) 10,000 — — Price differential ($/MMBtu) $ (0.13 ) $ — $ — Permian Basin index swap volume (b) 30,000 — — Price differential ($/MMBtu) $ 0.19 $ — $ — ____________________ (a) Represent swaps that fix the basis differentials between the index prices at which the Company sells its Gulf Coast, Mid-Continent and Permian Basin gas, respectively, and the HH index price used in gas swap and collar contracts. (b) Represent swaps that fix the basis differentials between Permian Basin index prices and southern California index prices for Permian Basin gas forecasted for sale in southern California. Marketing and basis differential derivative activities. Periodically, the Company enters into buy and sell marketing arrangements to fulfill firm pipeline transportation commitments. Associated with these marketing arrangements, the Company may enter into index swaps to mitigate price risk. As of September 30, 2015 , the Company had marketing oil index swap contracts for 10,000 Bbl per day for the remainder of 2015 with a price differential of $2.99 per Bbl between WTI and Louisiana Light Sweet oil. Interest rate derivative activities. As of September 30, 2015, the Company was party to interest rate derivative contracts whereby the Company will receive (i) the 10-year Treasury rate in exchange for paying average fixed rates of 2.15 percent on a notional amount of $100 million on December 15, 2015 and 2.24 percent on a notional amount of $100 million on March 15, 2016 and (ii) the three-month LIBOR rate for the 10-year period from March 2016 through March 2026 in exchange for paying a fixed interest rate of 2.18 percent on a notional amount of $50 million on March 15, 2016. Subsequent to September 30, 2015, the Company entered into additional interest rate derivative contracts whereby the Company will receive the three-month LIBOR rate for the 10-year period from March 2016 through March 2026 in exchange for paying a fixed interest rate of 2.12 percent on a notional amount of $50 million on March 15, 2016. Tabular disclosure of derivative financial instruments . All of the Company's derivatives are accounted for as non-hedge derivatives and therefore all changes in the fair values of its derivative contracts are recognized 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 as net current or noncurrent derivative assets or net current or noncurrent derivative liabilities, whichever the case may be, by commodity and counterparty. The Company enters into derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty. The aggregate fair value of the Company's derivative instruments reported in the accompanying consolidated balance sheets by type and counterparty, including the classification between current and noncurrent assets and liabilities, consists of the following: Fair Value of Derivative Instruments as of September 30, 2015 Type Consolidated Balance Sheet Location Fair Value Gross Amounts Offset in the Consolidated Balance Sheet Net Fair Value Presented in the Consolidated Balance Sheet (in millions) Derivatives not designated as hedging instruments Asset Derivatives: Commodity price derivatives Derivatives - current $ 634 $ (2 ) $ 632 Commodity price derivatives Derivatives - noncurrent $ 148 $ (1 ) 147 $ 779 Liability Derivatives: Commodity price derivatives Derivatives - current $ 2 $ (2 ) $ — Interest rate derivatives Derivatives - current $ 2 $ — 2 Commodity price derivatives Derivatives - noncurrent $ 2 $ (1 ) 1 $ 3 Fair Value of Derivative Instruments as of December 31, 2014 Type Consolidated Balance Sheet Location Fair Value Gross Amounts Offset in the Consolidated Balance Sheet Net Fair Value Presented in the Consolidated Balance Sheet (in millions) Derivatives not designated as hedging instruments Asset Derivatives: Commodity price derivatives Derivatives - current $ 579 $ (1 ) $ 578 Commodity price derivatives Derivatives - noncurrent $ 182 $ (1 ) 181 $ 759 Liability Derivatives: Commodity price derivatives Derivatives - current $ 1 $ (1 ) $ — Interest rate derivatives Derivatives - current $ 3 $ — 3 Commodity price derivatives Derivatives - noncurrent $ 3 $ (1 ) 2 $ 5 The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures. The following table details the location of gains and losses recognized on the Company's derivative contracts in the accompanying consolidated statements of operations: Derivatives Not Designated as Hedging Location of Gain / (Loss) Recognized in Three Months Ended Nine Months Ended Instruments Earnings on Derivatives 2015 2014 2015 2014 (in millions) Commodity price derivatives Derivative gains, net $ 575 $ 341 $ 614 $ 1 Interest rate derivatives Derivative gains, net (2 ) — 3 18 Total $ 573 $ 341 $ 617 $ 19

Exploratory Costs

Exploratory Costs	9 Months Ended
	Sep. 30, 2015
Exploratory Cost Disclosure [Abstract]
Exploratory Costs	Exploratory Costs The Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are presented in proved properties in the accompanying consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense. The following table reflects the Company's capitalized exploratory well and project activity during the three and nine months ended September 30, 2015 : Three Months Ended September 30, 2015 Nine Months Ended September 30, 2015 (in millions) Beginning capitalized exploratory costs $ 270 $ 305 Additions to exploratory costs pending the determination of proved reserves 321 782 Reclassification due to determination of proved reserves (319 ) (800 ) Exploratory well costs charged to exploration expense — (15 ) Ending capitalized exploratory costs $ 272 $ 272 As of September 30, 2015 and December 31, 2014 , the Company had no exploratory projects for which exploratory costs have been capitalized for a period greater than one year from the date drilling was completed.

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-term Debt Credit facility. The Company's long-term debt consists of senior notes, a revolving corporate credit facility and the effects of net deferred fair value hedge losses and issuance discounts. During August 2015, the Company entered into the Second Amendment to its Second Amended and Restated 5-Year Revolving Credit Agreement ("Credit Facility") with a syndicate of financial institutions to primarily extend the maturity of the credit facility from December 2017 to August 2020 while maintaining aggregate loan commitments of $1.5 billion . The Company accounted for the entry into the Credit Facility as a modification of the prior agreement and capitalized the debt issuance costs along with those unamortized issuance costs that remained from the issuance of the prior agreement. As of September 30, 2015 , the Company had no outstanding borrowings under the Credit Facility and was in compliance with its debt covenants. Senior notes. The Company's 5.875% senior notes (the "5.875% Senior Notes"), with outstanding debt principal balances of $455 million , are due to mature in July 2016. As the Company has the ability to fund any required cash payments upon the maturity of the 5.875% Senior Notes with its borrowing capacity under the Credit Facility, to the extent that they are not refinanced prior to their maturity, such notes are classified as long-term debt in the accompanying consolidated balance sheets.

Incentive Plans

Incentive Plans	9 Months Ended
	Sep. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Incentive Plans	Incentive Plans Stock-based compensation For the three and nine months ended September 30, 2015 , the Company recorded $26 million and $87 million , respectively, of stock-based compensation expense for all plans, as compared to $27 million and $89 million for the same respective periods of 2014 . As of September 30, 2015 , there was $131 million of unrecognized compensation expense related to unvested share-based compensation plan awards, including $21 million attributable to stock-based awards that are expected to be settled on their vesting date in cash, rather than in equity shares ("Liability Awards"). The unrecognized compensation expense will be recognized over the remaining vesting periods of the awards, which is a period of less than three years on a weighted average basis. As of September 30, 2015 and December 31, 2014 , accounts payable – due to affiliates includes $11 million and $23 million , respectively, of liabilities attributable to Liability Awards. The following table summarizes the activity that occurred during the nine months ended September 30, 2015 , for each type of share-based incentive award issued by Pioneer: Restricted Stock Equity Awards Restricted Stock Liability Awards Performance Units Stock Options Outstanding as of December 31, 2014 1,233,539 328,087 154,733 199,058 Awards granted 439,742 158,726 82,431 — Awards vested (525,494 ) (185,302 ) — — Awards forfeited (36,679 ) (28,851 ) — — Outstanding as of September 30, 2015 1,111,108 272,660 237,164 199,058

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company's asset retirement obligations primarily relate to the future plugging and abandonment of wells and facilities. The following table summarizes the Company's asset retirement obligation activity during the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Beginning asset retirement obligations $ 187 $ 193 $ 189 $ 194 New wells placed on production 1 1 2 3 Changes in estimates — 2 — 3 Dispositions — (5 ) — (7 ) Liabilities settled (9 ) (6 ) (18 ) (14 ) Accretion of discount 3 3 9 9 Ending asset retirement obligations $ 182 $ 188 $ 182 $ 188 The Company records the current and noncurrent portions of asset retirement obligations in other current liabilities and other liabilities, respectively, in the accompanying consolidated balance sheets. As of September 30, 2015 , the current portion of the Company's asset retirement obligations was $31 million , as compared to $28 million at December 31, 2014 .

Commitments And Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	Commitments and Contingencies The Company is a party to proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to such proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated. Obligations following divestitures. In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalty obligations and income taxes. The Company does not believe these obligations are probable of having a material impact on its liquidity, financial position or future results of operations.

Interest And Other Income

Interest And Other Income	9 Months Ended
	Sep. 30, 2015
Interest and Other Income [Abstract]
Interest And Other Income	Interest and Other Income The following table provides the components of the Company's interest and other income for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Equity interest in income of EFS Midstream (a) $ — $ 3 $ 5 $ 10 Deferred compensation plan income — — 4 3 Interest income 2 — 2 — Loss from vertical integration services (b) (20 ) (2 ) (16 ) (9 ) Other income 1 1 5 5 Total interest and other income $ (17 ) $ 2 $ — $ 9 ____________________ (a) The Company accounted for its investment in EFS Midstream LLC ("EFS Midstream") prior to its sale in July 2015 using the equity method. EFS Midstream provided gathering, treating and transportation services for the Company. See Note C for additional information on the Company's sale of EFS Midstream. (b) Loss from vertical integration services primarily represents net margins that result from Company-provided fracture stimulation and service operations, which are ancillary to and supportive of the Company's oil and gas joint operating activities, and do not represent intercompany transactions. For the three and nine months ended September 30, 2015 , these vertical integration net margins included $66 million and $264 million , respectively, of revenues and $86 million and $280 million , respectively, of costs and expenses. For the same periods in 2014 , these vertical integration net margins included $125 million and $321 million , respectively, of revenues and $127 million and $330 million , respectively, of costs and expenses.

Other Expense

Other Expense	9 Months Ended
	Sep. 30, 2015
Other Expense [Abstract]
Other Expense	Other Expense The following table provides the components of the Company's other expense for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Idle drilling and well service equipment charges (a) $ 22 $ 2 $ 73 $ 2 Transportation commitment charge (b) 11 11 38 34 Restructuring charges (c) 9 — 24 — Impairment of inventory and other property and equipment (d) 13 3 21 7 Other 5 4 14 12 Total other expense $ 60 $ 20 $ 170 $ 55 ____________________ (a) Primarily represents expenses attributable to idle drilling rig fees, which are not chargeable to joint operations. (b) Primarily represents firm transportation payments on excess pipeline capacity commitments. (c) Represents one-time restructuring costs associated with the Company's restructuring of its operations in Colorado, including closing its office in Denver, Colorado and eliminating its Trinidad-based pumping services operations. See Note B for additional information on the restructuring charges. (d) Primarily represents charges to reduce excess material and supplies inventories to their market values. See Note D for additional information on the fair value of materials and supplies inventory.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company's income tax benefit (provision) attributable to income from continuing operations consisted of the following for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Current tax benefit (provision) $ (48 ) $ 14 $ (49 ) $ (4 ) Deferred tax provision (307 ) (250 ) (146 ) (315 ) Income tax provision $ (355 ) $ (236 ) $ (195 ) $ (319 ) For both the three and nine months ended September 30, 2015 , the Company's effective tax rate, excluding income attributable to noncontrolling interests, was 35 percent , as compared to effective rates of 36 percent and 34 percent for the same respective periods in 2014 . During 2014, the Company's effective tax rates differed from the U.S. statutory rate of 35 percent primarily due to state income tax apportionments, nondeductible expenses and, for the nine months ended September 30, 2014, the recognition of a $21 million tax benefit resulting from the resolution during the first quarter of 2014 of a tax uncertainty related to net operating loss carryovers and alternative minimum tax credits obtained from the 2012 sand mine acquisition. The Company has no unrecognized tax benefits as of September 30, 2015 . The Company files income tax returns in the U.S. federal and various state and foreign jurisdictions. The Internal Revenue Service has closed examinations of the 2013 and prior tax years and, with few exceptions, the Company believes that it is no longer subject to examinations by state and foreign tax authorities for years before 2009. As of September 30, 2015 , no adjustments had been proposed in any jurisdiction that would have a significant effect on the Company's liquidity, future results of operations or financial position.

Net Income Per Share

Net Income Per Share	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Net Income Per Share	Net Income Per Share The following table reconciles the Company's income from continuing operations to basic and diluted net income attributable to common stockholders for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Income from continuing operations $ 648 $ 411 $ 356 $ 612 Participating basic earnings (6 ) (4 ) (3 ) (5 ) Basic and diluted income from continuing operations $ 642 $ 407 353 607 Basic and diluted loss from discontinued operations $ (2 ) $ (37 ) $ (6 ) $ (113 ) Basic and diluted net income attributable to common stockholders $ 640 $ 370 $ 347 $ 494 Basic weighted average common shares outstanding were 149 million for both the three and nine months ended September 30, 2015 and diluted weighted average common shares outstanding were 150 million and 149 million for the three and nine months ended September 30, 2015 , respectively. Basic and diluted weighted average common shares outstanding were 143 million for the three and nine months ended September 30, 2014 .

Basis Of Presentation (Policies

Basis Of Presentation (Policies)	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Presentation	Presentation. In the opinion of management, the consolidated financial statements of the Company as of September 30, 2015 and for the three and nine months ended September 30, 2015 and 2014 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 in or omitted from 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, 2014 . Certain reclassifications have been made to the 2014 financial statement and footnote amounts in order to conform to the 2015 presentation.
New Accounting Pronouncements, Policy [Policy Text Block]	New accounting pronouncements. In July 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory." ASU 2015-11 requires an entity to measure inventory at the lower of cost or net realizable value rather than lower of cost or market as previously required by GAAP. ASU 2015-11 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. This update should be applied prospectively with early application permitted. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements. In April 2015, the FASB issued ASU 2015-03, "Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs." ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Currently, debt issuance costs are recognized as deferred charges and recorded as assets. The guidance is effective for annual and interim periods beginning after December 15, 2015 with early adoption permitted and is to be implemented retrospectively. Adoption of the new guidance will only affect the presentation of the Company's consolidated balance sheets and will not have a material impact. In May 2014, the FASB issued ASU 2014-09, "Revenue from Contracts with Customers (Topic 606)," which supersedes the revenue recognition requirements in Accounting Standards Codification ("ASC") Topic 605, "Revenue Recognition," and most industry-specific guidance. ASU 2014-09 is based on the principle that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU 2015-14, which defers the effective date of ASU 2014-09 for one year to annual reports beginning after December 15, 2017. Early adoption is permitted as of the original effective date, December 15, 2016. Entities have the option of using either a full retrospective or modified approach to adopt the new standards. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	9 Months Ended
	Sep. 30, 2015
Acquisitions and Divestitures [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	The following table represents the components of the Company's discontinued operations for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Revenues and other income (a) $ — $ 50 $ 1 $ 234 Costs and expenses (b) (2 ) (108 ) (10 ) (408 ) Loss from discontinued operations before income taxes (2 ) (58 ) (9 ) (174 ) Current tax provision — — — (1 ) Deferred tax benefit — 21 3 62 Loss from discontinued operations, net of tax $ (2 ) $ (37 ) $ (6 ) $ (113 ) ____________________ (a) Primarily reflects oil and gas revenues and cash received associated with Alaskan Petroleum Production Tax credits on qualifying capital expenditures. (b) Costs and expenses during 2015 were primarily related to an arbitration award associated with plugging and abandonment obligations for two Gulf of Mexico wells from which Pioneer withdrew in 2009. Costs and expenses in 2014 were primarily comprised of oil and gas production costs and impairment charges. See Note D for information about impairment charges on the Barnett Shale assets and Pioneer Alaska.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Schedule of assets and liabilities measured at fair value on a recurring basis	The following table presents the Company's assets and liabilities that are measured at fair value on a recurring basis as of September 30, 2015 for each of the fair value hierarchy levels: Fair Value Measurement at September 30, 2015 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, 2015 (in millions) Assets: Commodity derivatives $ — $ 779 $ — $ 779 Deferred compensation plan assets 69 — — 69 Total assets 69 779 — 848 Liabilities: Commodity derivatives — 1 — 1 Interest rate derivatives — 2 — 2 Total liabilities — 3 — 3 Total recurring fair value measurements $ 69 $ 776 $ — $ 845
Fair Value Measurements, Nonrecurring [Table Text Block]	The following table presents the fair value and fair value adjustments (in millions) for the Company's March 2015 and September 2015 proved property impairments, as well as the average oil price per barrel ("Bbl") and gas price per British thermal unit ("MMBtu") utilized in respective Management's Price Outlooks: Management's Price Outlooks Fair Value Fair Value Adjustment Oil Gas West Panhandle March 2015 $ 61 $ (138 ) $ 65.02 $ 3.83 South Texas - Other September 2015 $ 88 $ (72 ) $ 57.41 $ 3.46
Fair Value of Assets Classified as Held for Sale [Table Text Block]	The following table presents the fair value adjustments made by the Company during 2014 related to assets associated with divestitures: Fair Value Adjustment Sales Value Less Costs to Sell Three Months Ended September 30, 2014 Nine Months Ended September 30, 2014 (in millions) Hugoton field $ 328 $ (34 ) $ (34 ) Barnett Shale field $ 149 $ (46 ) $ (174 ) Pioneer Alaska $ 253 $ — $ (97 )
Schedule of carrying values and financial instruments not carried at fair value	Carrying values and fair values of financial instruments that are not carried at fair value in the accompanying consolidated balance sheets as of September 30, 2015 and December 31, 2014 are as follows: September 30, 2015 December 31, 2014 Carrying Value Fair Value Carrying Value Fair Value (in millions) Long-term debt $ 2,675 $ 2,867 $ 2,665 $ 2,938

Derivative Financial Instrume25

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of oil derivative contracts volume and weighted average price	The following table sets forth the volumes per day associated with the Company's outstanding oil derivative contracts as of September 30, 2015 and the weighted average oil prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 2017 Swap contracts: Volume (Bbl) 82,000 4,475 — Price per Bbl $ 71.18 $ 59.00 $ — Collar contracts with short puts (a): Volume (Bbl) 15,000 101,806 34,000 Price per Bbl: Ceiling $ 97.69 $ 75.93 $ 70.42 Floor $ 82.97 $ 65.30 $ 57.65 Short put $ 69.67 $ 46.08 $ 47.65 Rollfactor swap contracts (b): Volume (Bbl) 37,000 — — NYMEX roll price $ 0.06 $ — $ — ____________________ (a) Counterparties have the option to extend for an additional year 5,000 Bbls per day of 2015 collar contracts with short puts with a ceiling price of $100.08 per Bbl, a floor price of $90.00 per Bbl and a short put price of $80.00 per Bbl. The option to extend is exercisable on December 31, 2015. These contracts give the counterparties the option to extend the contracts under the same terms for an additional year if the option to extend is exercised by the counterparties on December 31, 2015. (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 .
Schedule of NGL derivative volumes and weighted average prices	The following table sets forth the volumes per day associated with the Company's outstanding NGL derivative contracts as of September 30, 2015 and the weighted average NGL prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 Ethane swap contracts: Volume (Bbl) 6,000 5,000 Price per Bbl $ 7.80 $ 11.61 Propane swap contracts: Volume (Bbl) 11,000 7,500 Price per Bbl $ 21.62 $ 21.57
Schedule of gas derivative volume and weighted average prices	The following table sets forth the volumes per day associated with the Company's outstanding gas derivative contracts as of September 30, 2015 and the weighted average gas prices for those contracts: Three Months Ending December 31, Year Ending December 31, 2015 2016 2017 Swap contracts: Volume (MMBtu) 20,000 70,000 — Price per MMBtu $ 4.31 $ 4.06 $ — Collar contracts with short puts: Volume (MMBtu) 285,000 180,000 — Price per MMBtu: Ceiling $ 5.07 $ 4.01 $ — Floor $ 4.00 $ 3.24 $ — Short put $ 3.00 $ 2.78 $ — Basis swap contracts: Gulf Coast index swap volume (a) 20,000 10,000 — Price differential ($/MMBtu) $ — $ — $ — Mid-Continent index swap volume (a) 95,000 15,000 45,000 Price differential ($/MMBtu) $ (0.24 ) $ (0.32 ) $ (0.32 ) Permian Basin index swap volume (a) 10,000 — — Price differential ($/MMBtu) $ (0.13 ) $ — $ — Permian Basin index swap volume (b) 30,000 — — Price differential ($/MMBtu) $ 0.19 $ — $ — ____________________ (a) Represent swaps that fix the basis differentials between the index prices at which the Company sells its Gulf Coast, Mid-Continent and Permian Basin gas, respectively, and the HH index price used in gas swap and collar contracts. (b) Represent swaps that fix the basis differentials between Permian Basin index prices and southern California index prices for Permian Basin gas forecasted for sale in southern California.
Offsetting Asset and Liability	The aggregate fair value of the Company's derivative instruments reported in the accompanying consolidated balance sheets by type and counterparty, including the classification between current and noncurrent assets and liabilities, consists of the following: Fair Value of Derivative Instruments as of September 30, 2015 Type Consolidated Balance Sheet Location Fair Value Gross Amounts Offset in the Consolidated Balance Sheet Net Fair Value Presented in the Consolidated Balance Sheet (in millions) Derivatives not designated as hedging instruments Asset Derivatives: Commodity price derivatives Derivatives - current $ 634 $ (2 ) $ 632 Commodity price derivatives Derivatives - noncurrent $ 148 $ (1 ) 147 $ 779 Liability Derivatives: Commodity price derivatives Derivatives - current $ 2 $ (2 ) $ — Interest rate derivatives Derivatives - current $ 2 $ — 2 Commodity price derivatives Derivatives - noncurrent $ 2 $ (1 ) 1 $ 3 Fair Value of Derivative Instruments as of December 31, 2014 Type Consolidated Balance Sheet Location Fair Value Gross Amounts Offset in the Consolidated Balance Sheet Net Fair Value Presented in the Consolidated Balance Sheet (in millions) Derivatives not designated as hedging instruments Asset Derivatives: Commodity price derivatives Derivatives - current $ 579 $ (1 ) $ 578 Commodity price derivatives Derivatives - noncurrent $ 182 $ (1 ) 181 $ 759 Liability Derivatives: Commodity price derivatives Derivatives - current $ 1 $ (1 ) $ — Interest rate derivatives Derivatives - current $ 3 $ — 3 Commodity price derivatives Derivatives - noncurrent $ 3 $ (1 ) 2 $ 5
Schedule of derivative gains and losses recognized on statement of operations	The following table details the location of gains and losses recognized on the Company's derivative contracts in the accompanying consolidated statements of operations: Derivatives Not Designated as Hedging Location of Gain / (Loss) Recognized in Three Months Ended Nine Months Ended Instruments Earnings on Derivatives 2015 2014 2015 2014 (in millions) Commodity price derivatives Derivative gains, net $ 575 $ 341 $ 614 $ 1 Interest rate derivatives Derivative gains, net (2 ) — 3 18 Total $ 573 $ 341 $ 617 $ 19

Exploratory Costs (Tables)

Exploratory Costs (Tables)	9 Months Ended
	Sep. 30, 2015
Exploratory Cost Disclosure [Abstract]
Capitalized exploratory well and project activity	The following table reflects the Company's capitalized exploratory well and project activity during the three and nine months ended September 30, 2015 : Three Months Ended September 30, 2015 Nine Months Ended September 30, 2015 (in millions) Beginning capitalized exploratory costs $ 270 $ 305 Additions to exploratory costs pending the determination of proved reserves 321 782 Reclassification due to determination of proved reserves (319 ) (800 ) Exploratory well costs charged to exploration expense — (15 ) Ending capitalized exploratory costs $ 272 $ 272

Incentive Plans (Tables)

Incentive Plans (Tables)	9 Months Ended
	Sep. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of Share Based Incentive Award Activity	The following table summarizes the activity that occurred during the nine months ended September 30, 2015 , for each type of share-based incentive award issued by Pioneer: Restricted Stock Equity Awards Restricted Stock Liability Awards Performance Units Stock Options Outstanding as of December 31, 2014 1,233,539 328,087 154,733 199,058 Awards granted 439,742 158,726 82,431 — Awards vested (525,494 ) (185,302 ) — — Awards forfeited (36,679 ) (28,851 ) — — Outstanding as of September 30, 2015 1,111,108 272,660 237,164 199,058

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation [Abstract]
Schedule of asset retirement obligations	The following table summarizes the Company's asset retirement obligation activity during the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Beginning asset retirement obligations $ 187 $ 193 $ 189 $ 194 New wells placed on production 1 1 2 3 Changes in estimates — 2 — 3 Dispositions — (5 ) — (7 ) Liabilities settled (9 ) (6 ) (18 ) (14 ) Accretion of discount 3 3 9 9 Ending asset retirement obligations $ 182 $ 188 $ 182 $ 188

Interest And Other Income (Tabl

Interest And Other Income (Tables)	9 Months Ended
	Sep. 30, 2015
Interest and Other Income [Abstract]
Components of interest and other income	The following table provides the components of the Company's interest and other income for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Equity interest in income of EFS Midstream (a) $ — $ 3 $ 5 $ 10 Deferred compensation plan income — — 4 3 Interest income 2 — 2 — Loss from vertical integration services (b) (20 ) (2 ) (16 ) (9 ) Other income 1 1 5 5 Total interest and other income $ (17 ) $ 2 $ — $ 9 ____________________ (a) The Company accounted for its investment in EFS Midstream LLC ("EFS Midstream") prior to its sale in July 2015 using the equity method. EFS Midstream provided gathering, treating and transportation services for the Company. See Note C for additional information on the Company's sale of EFS Midstream. (b) Loss from vertical integration services primarily represents net margins that result from Company-provided fracture stimulation and service operations, which are ancillary to and supportive of the Company's oil and gas joint operating activities, and do not represent intercompany transactions. For the three and nine months ended September 30, 2015 , these vertical integration net margins included $66 million and $264 million , respectively, of revenues and $86 million and $280 million , respectively, of costs and expenses. For the same periods in 2014 , these vertical integration net margins included $125 million and $321 million , respectively, of revenues and $127 million and $330 million , respectively, of costs and expenses.

Other Expense (Tables)

Other Expense (Tables)	9 Months Ended
	Sep. 30, 2015
Other Expense [Abstract]
Schedule of components of other expense	The following table provides the components of the Company's other expense for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Idle drilling and well service equipment charges (a) $ 22 $ 2 $ 73 $ 2 Transportation commitment charge (b) 11 11 38 34 Restructuring charges (c) 9 — 24 — Impairment of inventory and other property and equipment (d) 13 3 21 7 Other 5 4 14 12 Total other expense $ 60 $ 20 $ 170 $ 55 ____________________ (a) Primarily represents expenses attributable to idle drilling rig fees, which are not chargeable to joint operations. (b) Primarily represents firm transportation payments on excess pipeline capacity commitments. (c) Represents one-time restructuring costs associated with the Company's restructuring of its operations in Colorado, including closing its office in Denver, Colorado and eliminating its Trinidad-based pumping services operations. See Note B for additional information on the restructuring charges. (d) Primarily represents charges to reduce excess material and supplies inventories to their market values. See Note D for additional information on the fair value of materials and supplies inventory.

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Income tax (provisions) benefits attributable to income from continuing operations	The Company's income tax benefit (provision) attributable to income from continuing operations consisted of the following for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Current tax benefit (provision) $ (48 ) $ 14 $ (49 ) $ (4 ) Deferred tax provision (307 ) (250 ) (146 ) (315 ) Income tax provision $ (355 ) $ (236 ) $ (195 ) $ (319 )

Net Income Per Share (Tables)

Net Income Per Share (Tables)	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Reconciliation of earnings attributable to common stockholders, basic and diluted	The following table reconciles the Company's income from continuing operations to basic and diluted net income attributable to common stockholders for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in millions) Income from continuing operations $ 648 $ 411 $ 356 $ 612 Participating basic earnings (6 ) (4 ) (3 ) (5 ) Basic and diluted income from continuing operations $ 642 $ 407 353 607 Basic and diluted loss from discontinued operations $ (2 ) $ (37 ) $ (6 ) $ (113 ) Basic and diluted net income attributable to common stockholders $ 640 $ 370 $ 347 $ 494

Basis Of Presentation Basis of

Basis Of Presentation Basis of Presentation (Restructuring) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Restructuring Cost and Reserve [Line Items]
Restructuring Charges	$ 9	$ 0	$ 24	$ 0
Restructuring and Related Cost, Expected Cost Remaining	3		3
Restructuring and Related Cost, Expected Cost	27		27
Restructuring Reserve	4		4
Employee Severance [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Expected Cost	18		18
Contract Termination [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Expected Cost	6		6
Employee Relocation [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Expected Cost	3		3
Cash [Member] | Employee Severance [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring Charges			17
Deferred Compensation, Share-based Payments [Member] | Employee Severance [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring Charges			1
Leasehold Improvements [Member] | Contract Termination [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Expected Cost	2		2
Property Subject to Operating Lease [Member] | Contract Termination [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Expected Cost	$ 4		$ 4

Acquisitions and Divestitures34

Acquisitions and Divestitures (Narrative) (Details) $ in Thousands		3 Months Ended		9 Months Ended		12 Months Ended
		Sep. 30, 2015USD ($)Rate	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)Rate	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)	Mar. 31, 2014
Acquisitions and Divestitures [Line Items]
Gain (loss) on disposition of assets, net		$ 779,000	$ 1,000	$ 782,000	$ 11,000
Equity Method Investment, Ownership Percentage | Rate		50.10%		50.10%
Equity Method Investment, Net Sales Proceeds				$ 1,000,000
Equity Method Investment, Realized Gain (Loss) on Disposal				778,000
Idle Rig Expense	[1]	$ 22,000	2,000	73,000	2,000
Proceeds from Sale of Productive Assets				556,000	855,000
Impairment of oil and gas properties		72,000	$ 0	210,000	0
Sendero [Member]
Acquisitions and Divestitures [Line Items]
Gain (loss) on disposition of assets, net					1,000
Proceeds from Divestiture of Interest in Consolidated Subsidiaries					31,000
Idle Rig Expense		$ 10,000		30,000
Gaines Dawson [Member]
Acquisitions and Divestitures [Line Items]
Gain (loss) on disposition of assets, net					2,000
Proceeds from Sale of Productive Assets					$ 72,000
Lease Contract through Year 2 [Member]
Acquisitions and Divestitures [Line Items]
Drilling rigs leased							12
Lease Contract for Year 3 [Member]
Acquisitions and Divestitures [Line Items]
Drilling rigs leased							8
Discontinued Operations [Member] | Hugoton field [Member]
Acquisitions and Divestitures [Line Items]
Proceeds from Sale of Productive Assets						$ 328,000
Discontinued Operations [Member] | Pioneer Alaska [Member]
Acquisitions and Divestitures [Line Items]
Proceeds from Sale of Productive Assets						267,000
Discontinued Operations [Member] | Barnett Shale Field [Member]
Acquisitions and Divestitures [Line Items]
Proceeds from Sale of Productive Assets						$ 150,000
Proceeds Received Current Year [Member]
Acquisitions and Divestitures [Line Items]
Equity Method Investment, Net Sales Proceeds				530,000
Proceeds To Be Received In Future Year [Member] [Member]
Acquisitions and Divestitures [Line Items]
Equity Method Investment, Net Sales Proceeds				$ 500,000
[1]	Primarily represents expenses attributable to idle drilling rig fees, which are not chargeable to joint operations.

Acquisitions and Divestitures A

Acquisitions and Divestitures Acquisitions and Divestitures (Components of Discontinued Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Oil and gas	$ 557,000	$ 967,000	$ 1,670,000	$ 2,795,000
Interest and other	(17,000)	2,000	0	9,000
Gain on disposition of assets, net	(779,000)	(1,000)	(782,000)	(11,000)
Oil and gas production	189,000	168,000	532,000	493,000
Production and ad valorem taxes	36,000	58,000	112,000	169,000
Depletion, depreciation and amortization	364,000	274,000	1,003,000	734,000
Impairment of oil and gas properties	72,000	0	210,000	0
Exploration and abandonment	25,000	22,000	79,000	80,000
General and administrative	81,000	81,000	246,000	244,000
Asset Retirement Obligation, Accretion Expense	3,000	3,000	9,000	9,000
Other Nonoperating Expense	60,000	20,000	170,000	55,000
Costs and Expenses	(1,215,000)	(866,000)	(3,183,000)	(2,457,000)
Current tax provision	(48,000)	14,000	(49,000)	(4,000)
Deferred tax benefit	(307,000)	(250,000)	(146,000)	(315,000)
Income (Loss) from Discontinued Operations, Net of Tax	(2,000)	(37,000)	(6,000)	(113,000)
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total Revenues And Other Income From Discontinued Operations	0	50,000	1,000	234,000
Costs and Expenses	(2,000)	(108,000)	(10,000)	(408,000)
Loss from discontinued operations before income taxes	(2,000)	(58,000)	(9,000)	(174,000)
Current tax provision	0	0	0	(1,000)
Deferred tax benefit	0	21,000	3,000	62,000
Income (Loss) from Discontinued Operations, Net of Tax	$ (2,000)	$ (37,000)	$ (6,000)	$ (113,000)

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule Of Assets And Liabilities Measured At Fair Value On A Recurring Basis) (Details) $ in Millions	Sep. 30, 2015USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred Compensation Plan Assets	$ 69
Assets, Fair Value Disclosure	848
Liabilities, Fair Value Disclosure	3
Recurring Measurements, (Fair Value, Total)	845
Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred Compensation Plan Assets	69
Assets, Fair Value Disclosure	69
Liabilities, Fair Value Disclosure	0
Recurring Measurements, (Fair Value, Total)	69
Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred Compensation Plan Assets	0
Assets, Fair Value Disclosure	779
Liabilities, Fair Value Disclosure	3
Recurring Measurements, (Fair Value, Total)	776
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred Compensation Plan Assets	0
Assets, Fair Value Disclosure	0
Liabilities, Fair Value Disclosure	0
Recurring Measurements, (Fair Value, Total)	0
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	2
Interest Rate Derivatives [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	0
Interest Rate Derivatives [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	2
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	0
Commodity Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	779
Derivative Liability, Fair Value, Net	1
Commodity Derivatives [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	0
Derivative Liability, Fair Value, Net	0
Commodity Derivatives [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	779
Derivative Liability, Fair Value, Net	1
Commodity Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	0
Derivative Liability, Fair Value, Net	$ 0

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2015USD ($)$ / MMBTU$ / bbl	Mar. 31, 2015USD ($)$ / MMBTU$ / bbl	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Inventory Write-down	$ 12,000			$ 20,000
Impairment of oil and gas properties	$ (72,000)		$ 0	(210,000)	$ 0
Management oil price outlook | $ / bbl	57.41	65.02
Management gas price outlook | $ / MMBTU	3.46	3.83
West Panhandle [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Asset Group		$ 61,000
Impairment of oil and gas properties		$ (138,000)
South Texas Edwards And Austin Chalk [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Asset Group	$ 88,000			$ 88,000
Impairment of oil and gas properties	$ (72,000)

Fair Value Measurements Fair 38

Fair Value Measurements Fair Value Measurements (Fair Value of Assets Classified as Held For Sale (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Mar. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and gas properties	$ (72,000)	$ 0	$ (210,000)	$ 0
Hugoton field [Member] | Discontinued Operations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Asset Group		328,000		328,000
Impairment of oil and gas properties		(34,000)		(34,000)
Barnett Shale Field [Member] | Discontinued Operations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Asset Group		149,000		149,000
Impairment of oil and gas properties		(46,000)		(174,000)
Pioneer Alaska [Member] | Discontinued Operations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Asset Group					$ 253,000
Impairment of oil and gas properties		$ 0		$ (97,000)

Fair Value Measurements (Sche39

Fair Value Measurements (Schedule Of Carrying Values And Financial Instruments Not Carried At Fair Value) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Document Period End Date	Sep. 30, 2015
Long-term Debt, Excluding Current Maturities	$ 2,675	$ 2,665
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Excluding Current Maturities	2,675	2,665
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Excluding Current Maturities	$ 2,867	$ 2,938

Derivative Financial Instrume40

Derivative Financial Instruments (Narrative) (Details) - USD ($) $ in Millions	Nov. 02, 2015	Sep. 30, 2015
December 15, 2015 Interest Rate Swaps [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Derivative, Fixed Interest Rate		2.15%
Notional amount of debt		$ 100
March 15, 2016 Interest Rate Swaps [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Derivative, Fixed Interest Rate		2.24%
Notional amount of debt		$ 100
March 2016 Interest Rate Swaps [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Derivative, Fixed Interest Rate		2.18%
Notional amount of debt		$ 50
Subsequent Event [Member] | March 2016 Interest Rate Swaps [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Derivative, Fixed Interest Rate	2.12%
Notional amount of debt	$ 50

Derivative Financial Instrume41

Derivative Financial Instruments (Schedule Of Oil Derivative Contracts Volume And Weighted Average Prices) (Details)	Sep. 30, 2015bbl / d$ / bbl
Rollfactor Swap Contracts [Member]
Derivative [Line Items]
NYMEX swap multiple, second nearby month	0.6667
NYMEX swap multiple, third nearby month	0.3333
Oil contracts [Member] | Collar Contracts With Short Puts for Current Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	15,000
Oil contracts [Member] | Collar Contracts With Short Puts for Year 2 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	101,806	[1],[2]
Oil contracts [Member] | Collar Contracts With Short Puts for Year 3 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	34,000	[1]
Oil contracts [Member] | Collar Contracts With Short Puts for Year 2 - Extendible for Year 3 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	5,000
Oil contracts [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	82,000
Oil contracts [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	4,475
Oil contracts [Member] | Swap Contracts for Year 3 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	0
Oil contracts [Member] | Rollfactor Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	37,000
Oil contracts [Member] | Rollfactor Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	0
Oil contracts [Member] | Rollfactor Swap Contracts for Year 3 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	0
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Current Year [Member]
Derivative [Line Items]
Derivative, Average Cap Price	97.69
Derivative, Average Floor Price	82.97
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Current Year [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	69.67
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 2 [Member]
Derivative [Line Items]
Derivative, Average Cap Price	75.93
Derivative, Average Floor Price	65.30
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 2 [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	46.08
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 3 [Member]
Derivative [Line Items]
Derivative, Average Cap Price	70.42
Derivative, Average Floor Price	57.65
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 3 [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	47.65
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 2 - Extendible for Year 3 [Member]
Derivative [Line Items]
Derivative, Average Cap Price	100.08
Derivative, Average Floor Price	90
Oil contracts, price per bbl [Member] | Collar Contracts With Short Puts for Year 2 - Extendible for Year 3 [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	80
Oil contracts, price per bbl [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	71.18
Oil contracts, price per bbl [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	59
Oil contracts, price per bbl [Member] | Swap Contracts for Year 3 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Oil contracts, price per bbl [Member] | Rollfactor Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0.06
Oil contracts, price per bbl [Member] | Rollfactor Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0	[3]
Oil contracts, price per bbl [Member] | Rollfactor Swap Contracts for Year 3 [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	0
[1]	(a)Counterparties have the option to extend for an additional year 5,000 Bbls per day of 2015 collar contracts with short puts with a ceiling price of $100.08 per Bbl, a floor price of $90.00 per Bbl and a short put price of $80.00 per Bbl. The option to extend is exercisable on December 31, 2015. These contracts give the counterparties the option to extend the contracts under the same terms for an additional year if the option to extend is exercised by the counterparties on December 31, 2015.
[2]	.
[3]	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.

Derivative Financial Instrume42

Derivative Financial Instruments Derivative Financial Instruments (Schedule of NGL Derivative Contracts Volume and Weighted Average Prices) (Details)	Sep. 30, 2015bbl / d$ / bbl
Propane [Member] | NGL contract, in BBLS [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	11,000
Propane [Member] | NGL contract, in BBLS [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	7,500
Propane [Member] | NGL contracts, price per BBL [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	21.62
Propane [Member] | NGL contracts, price per BBL [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	21.57
Ethane [Member] | NGL contract, in BBLS [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	6,000
Ethane [Member] | NGL contract, in BBLS [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	5,000
Ethane [Member] | NGL contracts, price per BBL [Member] | Swap Contracts for Current Year [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	7.80
Ethane [Member] | NGL contracts, price per BBL [Member] | Swap Contracts for Year 2 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	11.61

Derivative Financial Instrume43

Derivative Financial Instruments Derivative Financial Instruments (Schedule of Gas Derivative Contracts Volume and Weighted Average Prices) (Details)	Sep. 30, 2015MMBTU / d$ / MMBTU
Collar Contracts With Short Puts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	285,000
Collar Contracts With Short Puts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Average Cap Price	5.07
Derivative, Average Floor Price	4
Collar Contracts With Short Puts for Current Year [Member] | Gas contracts, price per MMBTU [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	3
Collar Contracts With Short Puts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	180,000
Collar Contracts With Short Puts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Average Cap Price	4.01
Derivative, Average Floor Price	3.24
Collar Contracts With Short Puts for Year 2 [Member] | Gas contracts, price per MMBTU [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	2.78
Collar Contracts With Short Puts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0
Collar Contracts With Short Puts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Average Cap Price	0
Derivative, Average Floor Price	0
Collar Contracts With Short Puts for Year 3 [Member] | Gas contracts, price per MMBTU [Member] | Short Put [Member]
Derivative [Line Items]
Derivative, Notional Amount, Price Per Unit	0
Swap Contracts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	20,000
Swap Contracts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	4.31
Swap Contracts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	70,000
Swap Contracts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	4.06
Swap Contracts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0
Swap Contracts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Gulf Coast [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	20,000
Gulf Coast [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Gulf Coast [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	10,000	[1]
Gulf Coast [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Gulf Coast [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0	[1]
Gulf Coast [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Mid-Continent [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	95,000
Mid-Continent [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.24)
Mid-Continent [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	15,000	[1]
Mid-Continent [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.32)
Mid-Continent [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	45,000	[1],[2]
Mid-Continent [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.32)
Permian Basin [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	10,000
Permian Basin [Member] | Basis Swap Contracts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	(0.13)
Permian Basin [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0	[1]
Permian Basin [Member] | Basis Swap Contracts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Permian Basin [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0	[1]
Permian Basin [Member] | Basis Swap Contracts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Permian Basin [Member] | So Cal Basis Swap Contracts for Current Year [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	30,000
Permian Basin [Member] | So Cal Basis Swap Contracts for Current Year [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0.19
Permian Basin [Member] | So Cal Basis Swap Contracts for Year 2 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0
Permian Basin [Member] | So Cal Basis Swap Contracts for Year 2 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
Permian Basin [Member] | So Cal Basis Swap Contracts for Year 3 [Member] | Gas contracts, in MMBTU [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	0
Permian Basin [Member] | So Cal Basis Swap Contracts for Year 3 [Member] | Gas contracts, price per MMBTU [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	0
[1]	(a)Represent swaps that fix the basis differentials between the index prices at which the Company sells its Gulf Coast, Mid-Continent and Permian Basin gas, respectively, and the HH index price used in gas swap and collar contracts.
[2]	(b)

Derivative Financial Instrume44

Derivative Financial Instruments Derivative Financial Instruments (Schedule of Marketing Derivative Contracts Volume and Weighted Average Prices) (Details) (Details) - Basis Swap Contracts for Current Year [Member]	Sep. 30, 2015MMBTU / d$ / bbl
Marketing Oil contracts, in BBL [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	10,000
Marketing oil contracts, price per BBL [Member] [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	2.99

Derivative Financial Instrume45

Derivative Financial Instruments (Schedule Of Derivative Instruments) (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative Assets, Current	$ 632	$ 578
Derivative Assets, Noncurrent	147	181
Derivative Liabilities, Current	2	3
Derivative Liabilities, Noncurrent	1	2
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Net	779	759
Derivative Liability, Fair Value, Net	3	5
Not Designated as Hedging Instrument [Member] | Commodity Price Derivatives [Member] | Derivatives - Current [Member]
Derivative [Line Items]
Total derivatives, Asset, Gross	634	579
Derivative Liability, Fair Value, Gross Liability	2	1
Derivative Assets Offset In Balance Sheet	(2)	(1)
Derivative Liabilities Offset In Balance Sheet	(2)	(1)
Derivative Assets, Current	632	578
Derivative Liabilities, Current	0	0
Not Designated as Hedging Instrument [Member] | Commodity Price Derivatives [Member] | Derivatives - Noncurrent [Member]
Derivative [Line Items]
Total derivatives, Asset, Gross	148	182
Derivative Liability, Fair Value, Gross Liability	2	3
Derivative Assets Offset In Balance Sheet	(1)	(1)
Derivative Liabilities Offset In Balance Sheet	(1)	(1)
Derivative Assets, Noncurrent	147	181
Derivative Liabilities, Noncurrent	1	2
Not Designated as Hedging Instrument [Member] | Interest Rate Derivatives [Member] | Derivatives - Current [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability	2	3
Derivative Liabilities Offset In Balance Sheet	0	0
Derivative Liabilities, Current	$ 2	$ 3

Derivative Financial Instrume46

Derivative Financial Instruments (Schedule Of Derivative Obligations Under Terminated Hedge Arrangements) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative [Line Items]
Derivative gains, net	$ 573	$ 341	$ 617	$ 19
Commodity Price Derivatives [Member] | Derivative Gains (Losses), Net [Member]
Derivative [Line Items]
Derivative gains, net	575	341	614	1
Interest Rate Derivatives [Member] | Derivative Gains (Losses), Net [Member]
Derivative [Line Items]
Derivative gains, net	$ (2)	$ 0	$ 3	$ 18

Exploratory Costs (Schedule Of

Exploratory Costs (Schedule Of Capitalized Exploratory Well And Project Activity) (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2014
Beginning capitalized exploratory costs	$ 270	$ 305
Additions to exploratory costs pending the determination of proved reserves	321	782
Reclassification due to determination of proved reserves	(319)	(800)
Exploratory well costs charged to exploration expense	0	(15)
Ending capitalized exploratory costs	$ 272	$ 272
Number of projects with exploratory costs that have been suspended for a period greater than one year	0	0	0

Exploratory Costs Exploratory C

Exploratory Costs Exploratory Costs (Narrative) (Details)	Sep. 30, 2015	Dec. 31, 2014
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Number of projects with exploratory costs that have been suspended for a period greater than one year	0	0

Long-Term Debt (Details)

Long-Term Debt (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)Rate
Debt Instrument [Line Items]
Maximum Borrowing Capacity	$ 1,500
Document Period End Date	Sep. 30, 2015
Outstanding borrowing	$ 0
Five Point Eight Seven Five Percent Senior Notes Due Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage | Rate	5.875%
Senior Notes	$ 455

Incentive Plans Incentive Plans

Incentive Plans Incentive Plans (Stock-based compensation) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred Compensation Arrangement with Individual, Compensation Expense	$ 26	$ 27	$ 87	$ 89
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	131		$ 131
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
Restricted Stock Liability Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	21		$ 21
Accounts Payable, Current	$ 11		$ 11		$ 23

Incentive Plans Incentive Pla51

Incentive Plans Incentive Plans (Share Based Incentive Award Activity) (Details) - shares	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Restricted Stock Equity Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,111,108	1,233,539
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	439,742
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(525,494)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(36,679)
Restricted Stock Liability Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	272,660	328,087
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	158,726
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(185,302)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(28,851)
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	237,164	154,733
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	82,431
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	0
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	199,058	199,058
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	0

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning asset retirement obligations	$ 187	$ 193	$ 189	$ 194
Asset Retirement Obligation, Liabilities Incurred	1	1	2	3
Changes in estimates	0	2	0	3
Disposition of wells	0	(5)	0	(7)
Liabilities settled	(9)	(6)	(18)	(14)
Accretion of discount from continuing operations	3	3	9	9
Ending asset retirement obligations	182	$ 188	182	$ 188
Asset retirement obligations, current portions	$ 31		$ 31		$ 28

Interest And Other Income (Comp

Interest And Other Income (Components Of Interest And Other Income) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Interest and Other Income [Abstract]
Equity interest in income of unconsolidated affiliate	[1]	$ 0	$ 3	$ 5	$ 10
Deferred compensation plan income		0	0	4	3
Interest income		2	0	2	0
Third-party income (loss) from vertical integration services	[2]	(20)	(2)	(16)	(9)
Other income		1	1	5	5
Total interest and other income		(17)	2	0	9
GrossRevenuesIncludedInThirdPartyIncomeFromVerticalIntegrationServices		66	125	264	321
GrossExpensesIncludedInThirdPartyIncomeFromVerticalIntegrationServices		$ 86	$ 127	$ 280	$ 330
[1]	(a)The Company accounted for its investment in EFS Midstream LLC ("EFS Midstream") prior to its sale in July 2015 using the equity method. EFS Midstream provided gathering, treating and transportation services for the Company.
[2]	(b)Loss from vertical integration services primarily represents net margins that result from Company-provided fracture stimulation and service operations, which are ancillary to and supportive of the Company's oil and gas joint operating activities, and do not represent intercompany transactions. For the three and nine months ended September 30, 2015, these vertical integration net margins included $66 million and $264 million, respectively, of revenues and $86 million and $280 million, respectively, of costs and expenses. For the same periods in 2014, these vertical integration net margins included $125 million and $321 million, respectively, of revenues and $127 million and $330 million, respectively, of costs and expenses.

Other Expense (Schedule Of Comp

Other Expense (Schedule Of Components Of Other Expense) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Other Expense [Abstract]
Above market and idle drilling and well services equipment charges	[1]	$ 22	$ 2	$ 73	$ 2
Transportation commitment charges	[2]	11	11	38	34
Restructuring Charges		9	0	24	0
Inventory valuation charges	[3]	13	3	21	7
Other		5	4	14	12
Total other expense		$ 60	$ 20	$ 170	$ 55
[1]	Primarily represents expenses attributable to idle drilling rig fees, which are not chargeable to joint operations.
[2]	Primarily represents firm transportation payments on excess pipeline capacity commitments.
[3]	Primarily represents charges to reduce excess material and supplies inventories to their market values. See Note D for additional information on the fair value of materials and supplies inventory.

Income Taxes (Schedule Of Incom

Income Taxes (Schedule Of Income Tax (Provisions) Benefits Attributable To Income From Continuing Operations) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Tax Disclosure [Abstract]
Current income taxes	$ (48,000,000)	$ 14,000,000	$ (49,000,000)	$ (4,000,000)
Deferred income taxes	(307,000,000)	(250,000,000)	(146,000,000)	(315,000,000)
Income tax benefit (provision)	$ (355,000,000)	$ (236,000,000)	$ (195,000,000)	$ (319,000,000)
Effective Tax Rate		36.00%	35.00%	34.00%
Statutory Tax Rate	35.00%	35.00%	35.00%	35.00%
Unrecognized tax benefit recognized in period				$ 21,000,000
Unrecognized Tax Benefits	$ 0		$ 0

Net Income Per Share (Reconcili

Net Income Per Share (Reconciliation Of Earnings Attributable To Common Stockholders, Basic And Diluted) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement Operating Activities Segment [Line Items]
Basic income (loss) from continuing operations attributable to common stockholders	$ 640	$ 370	$ 347	$ 494
Diluted income (loss) from continuing operations attributable to common stockholders	640	370	347	494
Continuing Operations [Member]
Statement Operating Activities Segment [Line Items]
Income (loss) from continuing operations attributable to parent	648	411	356	612
Participating Securities, Distributed and Undistributed Earnings, Basic	(6)	(4)	(3)	(5)
Basic income (loss) from continuing operations attributable to common stockholders	642	407	353	607
Diluted income (loss) from continuing operations attributable to common stockholders	642	407	353	607
Discontinued Operations [Member]
Statement Operating Activities Segment [Line Items]
Basic income (loss) from continuing operations attributable to common stockholders	(2)	(37)	(6)	(113)
Diluted income (loss) from continuing operations attributable to common stockholders	$ (2)	$ (37)	$ (6)	$ (113)

Net Income Per Share (Reconci57

Net Income Per Share (Reconciliation Of Basic To Diluted Weighted Average Common Shares Outstanding) (Details) - shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Weighted Average Number of Shares Outstanding Reconciliation [Line Items]
Basic	149	143	149	143
Diluted	150	143	149	143