Apache 8-K 4 Aug 16 2015 FY Other Events Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016	Jun. 30, 2015
Document And Entity Information [Abstract]
Document Type	8-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	APA
Entity Registrant Name	APACHE CORP
Entity Central Index Key	6,769
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		378,297,784
Entity Public Float			$ 21,783,122,197

Statement of Consolidated Opera

Statement of Consolidated Operations - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Oil and gas production revenues:
Oil and gas production revenues	$ 6,510	$ 12,795	$ 14,825
Other	98	285	(315)
Gain (loss) on divestiture	281	(1,608)	(1,231)
Total revenues and other	6,889	11,472	13,279
OPERATING EXPENSES:
Lease operating expenses	1,854	2,238	2,650
Gathering and transportation	211	273	288
Taxes other than income	282	577	772
Exploration Expense	2,771	2,499	942
General and administrative	380	453	491
Oil and gas property and equipment
Depreciation, depletion, and amortization	3,300	4,526	5,057
Asset retirement obligation accretion	145	154	211
Impairments	9,472	7,102	1,443
Transaction, reorganization, and separation	132	67	33
Financing costs, net	511	413	445
Total operating expenses	19,058	18,302	12,332
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(12,169)	(6,830)	947
Current income tax provision	435	1,281	1,673
Deferred income tax provision (benefit)	(1,445)	(1,799)	(732)
Net income (loss) from continuing operations including noncontrolling interest	(11,159)	(6,312)	6
Net income (loss) from discontinued operations, net of tax	492	(1,707)	438
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(10,667)	(8,019)	444
Preferred stock dividends	0	0	44
Net income (loss) attributable to noncontrolling interest	(315)	341	56
Net income (loss) attributable to common shareholders	(10,352)	(8,360)	344
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS:
Net income (loss) from continuing operations attributable to common shareholders	(10,844)	(6,653)	(94)
Net income (loss) from discontinued operations	492	(1,707)	438
Net income (loss) attributable to common shareholders	$ (10,352)	$ (8,360)	$ 344
BASIC NET INCOME (LOSS) PER COMMON SHARE:
Basic net income (loss) from continuing operations per share	$ (28.70)	$ (17.32)	$ (0.24)
Basic net income (loss) from discontinued operations per share	1.30	(4.44)	1.11
Basic net income (loss) per share	(27.40)	(21.76)	0.87
DILUTED NET INCOME (LOSS) PER COMMON SHARE:
Diluted net income (loss) from continuing operations per share	(28.70)	(17.32)	(0.24)
Diluted net income (loss) from discontinued operations per share	1.30	(4.44)	1.11
Diluted net income (loss) per share	$ (27.40)	$ (21.76)	$ 0.87
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic	378	384	395
Diluted	378	384	395
DIVIDENDS DECLARED PER COMMON SHARE	$ 1	$ 1	$ 0.80
Oil and gas property and equipment [Member]
Oil and gas property and equipment
Depreciation, depletion, and amortization	$ 2,976	$ 4,195	$ 4,705
Other assets [Member]
Oil and gas property and equipment
Depreciation, depletion, and amortization	324	331	352
Oil [Member]
Oil and gas production revenues:
Oil and gas production revenues	5,107	10,110	11,870
Natural Gas [Member]
Oil and gas production revenues:
Oil and gas production revenues	1,176	2,017	2,303
Natural Gas Liquids [Member]
Oil and gas production revenues:
Oil and gas production revenues	$ 227	$ 668	$ 652

Statement of Consolidated Compr

Statement of Consolidated Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	$ (10,667)	$ (8,019)	$ 444
OTHER COMPREHENSIVE INCOME (LOSS):
Pension and postretirement benefit plan, net of tax	(3)	0	9
Commodity cash flow hedge activity, net of tax:
Reclassification of (gain) loss on settled derivative instruments	0	0	11
Change in fair value of derivative instruments	0	(1)	(5)
Derivative hedge ineffectiveness reclassified into earnings	0	0	1
Commodity cash flow hedge activity, net of tax	(3)	(1)	16
COMPREHENSIVE INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(10,670)	(8,020)	460
Preferred stock dividends	0	0	44
Comprehensive income (loss) attributable to noncontrolling interest	(315)	341	56
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$ (10,355)	$ (8,361)	$ 360

Statement of Consolidated Cash

Statement of Consolidated Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	$ (10,667)	$ (8,019)	$ 444
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Loss (income) from discontinued operations	(492)	1,707	(438)
Gain (Loss) on Disposition of Business	(281)	1,608	1,231
Exploratory dry hole expense and unproved leasehold impairments	2,595	2,294	729
Depreciation, depletion, and amortization	3,300	4,526	5,057
Asset retirement obligation accretion	145	154	211
Impairments	9,472	7,102	1,443
Provision for (benefit from) deferred income taxes	(1,445)	(1,799)	(732)
Other	7	(231)	300
Changes in operating assets and liabilities:
Receivables	663	757	105
Inventories	21	(31)	(65)
Drilling advances	138	107	269
Deferred charges and other	(345)	(301)	(148)
Accounts payable	(489)	(216)	286
Accrued expenses	(156)	(572)	(467)
Deferred credits and noncurrent liabilities	88	(73)	39
NET CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	2,554	7,013	8,264
NET CASH PROVIDED BY DISCONTINUED OPERATIONS	113	944	1,164
NET CASH PROVIDED BY OPERATING ACTIVITIES	2,667	7,957	9,428
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(4,208)	(8,608)	(8,242)
Additions to gas gathering, transmission, and processing facilities	(233)	(881)	(464)
Leasehold and property acquisitions	(367)	(1,475)	(429)
Proceeds from sale of Kitimat LNG	854
Proceeds from sale of Yara Pilbara	391
Proceeds from sale of productive assets	391	1,262	3,702
Proceeds from Kitimat LNG transaction, net			396
Proceeds from sale of oil and gas assets	268	470	307
Other, net	6	(299)	(105)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	(3,289)	(8,171)	(4,835)
NET CASH PROVIDED BY (USED IN) DISCONTINUED OPERATIONS	4,372	(219)	(1,874)
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES	1,083	(8,390)	(6,709)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper, credit facilities and bank notes, net	(1,570)	1,568	(509)
Payments on fixed rate debt	(939)		(2,072)
Distributions to noncontrolling interest	(129)	(140)
Proceeds from sale of noncontrolling interest			2,948
Dividends paid	(377)	(365)	(360)
Treasury stock activity, net		(1,864)	(997)
Other	53	49	21
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	(2,962)	(752)	(969)
NET CASH USED IN DISCONTINUED OPERATIONS		(42)	(4)
NET CASH USED IN FINANCING ACTIVITIES	(2,962)	(794)	(973)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	788	(1,227)	1,746
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	679	1,906	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	1,467	679	1,906
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest	461	260	350
Income taxes paid, net of refunds	$ 573	1,357	1,766
Deepwater Gulf of Mexico [Member]
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of productive assets		1,360
Anadarko Basin and Southern Louisiana [Member]
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of productive assets		$ 1,262
Gulf of Mexico Shelf [Member]
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of productive assets			$ 3,702

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
CURRENT ASSETS:
Cash and cash equivalents	$ 1,467	$ 679
Receivables, net of allowance	1,253	2,019
Inventories	570	681
Drilling advances	172	283
Assets held for sale		3,381
Deferred tax asset		890
Prepaid assets and other	290	129
Total current assets	3,752	8,062
Oil and gas, on the basis of full-cost accounting:
Proved properties	41,728	49,376
Unproved properties and properties under development, not being amortized	2,277	5,490
Gathering, transmission, and processing facilities	1,052	5,440
Other	1,093	1,152
Property and equipment, gross	46,150	61,458
Less: Accumulated depreciation, depletion, and amortization	(25,312)	(26,813)
Property and equipment, net	20,838	34,645
OTHER ASSETS:
Deferred charges and other	910	1,557
Total assets	25,500	44,264
CURRENT LIABILITIES:
Accounts payable	618	1,110
Liabilities held for sale		428
Other current liabilities	1,223	2,240
Total current liabilities	1,841	3,778
Long-term debt	8,716	11,178
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	2,529	5,493
Asset retirement obligation	2,562	2,915
Other	362	359
Total deferred credits and other noncurrent liabilities	5,453	8,767
COMMITMENTS AND CONTINGENCIES (Note 8)
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 411,218,105 and 409,706,347 shares issued, respectively	257	256
Paid-in capital	12,619	12,590
Retained earnings (accumulated deficit)	(1,980)	8,655
Treasury stock, at cost, 33,183,930 and 33,201,455 shares, respectively	(2,889)	(2,890)
Accumulated other comprehensive loss	(119)	(116)
APACHE SHAREHOLDERS' EQUITY	7,888	18,495
Noncontrolling interest	1,602	2,046
TOTAL EQUITY	9,490	20,541
TOTAL LIABILITIES AND EQUITY	$ 25,500	$ 44,264

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Common stock, par value	$ 0.625	$ 0.625
Common stock, shares authorized	860,000,000	860,000,000
Common stock, shares issued	411,218,105	409,706,347
Treasury stock, shares	33,183,930	33,201,455

Statement of Consolidated Chang

Statement of Consolidated Changes in Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Paid-In Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive (Loss) [Member]	Parent [Member]	Noncontrolling Interest [Member]	Series D Preferred Stock [Member]
Effect of change in accounting principle | Restatement Adjustment [Member]	$ (2,793)			$ (2,793)			$ (2,793)
Beginning Balance (Scenario, Previously Reported [Member]) at Dec. 31, 2012	31,331	$ 245	$ 9,859	20,161	$ (30)	$ (131)	31,331		$ 1,227
Beginning Balance at Dec. 31, 2012	28,538	245	9,859	17,368	(30)	(131)	28,538		1,227
Net income (loss)	444			388			388	$ 56
Pension and postretirement benefit plan, net of tax	9					9	9
Commodity hedges, net of tax	7					7	7
Preferred	(44)			(44)			(44)
Common dividends	(317)			(317)			(317)
Common stock activity, net	(21)	1	(22)				(21)
Treasury stock activity, net	(997)				(997)		(997)
Sale of noncontrolling interest	2,948		1,159				1,159	1,789
Conversion of Series D preferred stock		9	1,218						$ (1,227)
Compensation expense	189		189				189
Ending Balance at Dec. 31, 2013	30,756	255	12,403	17,395	(1,027)	(115)	28,911	1,845
Net income (loss)	(8,019)			(8,360)			(8,360)	341
Pension and postretirement benefit plan, net of tax	0
Distributions to noncontrolling interest	(140)							(140)
Commodity hedges, net of tax	(1)					(1)	(1)
Common dividends	(380)			(380)			(380)
Common stock activity, net	(10)	1	(11)				(10)
Treasury stock activity, net	(1,864)		(1)		(1,863)		(1,864)
Compensation expense	202		202				202
Other	(3)		(3)				(3)
Ending Balance at Dec. 31, 2014	20,541	256	12,590	8,655	(2,890)	(116)	18,495	2,046
Net income (loss)	(10,667)			(10,352)			(10,352)	(315)
Pension and postretirement benefit plan, net of tax	(3)					(3)	(3)
Distributions to noncontrolling interest	(129)							(129)
Common dividends	(378)		(95)	(283)			(378)
Common stock activity, net	(14)	1	(15)				(14)
Treasury stock activity, net			(1)		1
Compensation expense	140		140				140
Ending Balance at Dec. 31, 2015	$ 9,490	$ 257	$ 12,619	$ (1,980)	$ (2,889)	$ (119)	$ 7,888	$ 1,602

Statement of Consolidated Chan8

Statement of Consolidated Changes in Equity (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income tax benefit (expense) to post retirement			$ 9
Tax (benefit) expense to commodity hedges			$ 4
Common stock, dividends, per share	$ 1	$ 1	$ 0.80
Paid-In Capital [Member]
Common stock, dividends, per share	1
Retained Earnings (Accumulated Deficit) [Member]
Common stock, dividends, per share	1	1	$ 0.80
Accumulated Other Comprehensive (Loss) [Member]
Income tax benefit (expense) to post retirement			$ 9
Tax (benefit) expense to commodity hedges			4
Parent [Member]
Income tax benefit (expense) to post retirement			9
Tax (benefit) expense to commodity hedges			$ 4
Common stock, dividends, per share	$ 1	$ 1	$ 0.80

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Accounting policies used by Apache and its subsidiaries reflect industry practices and conform to accounting principles generally accepted in the U.S. (GAAP). The Company’s financial statements for prior periods include reclassifications that were made to conform to the current-year presentation. During the second quarter of 2015, Apache completed the sale of its Australian LNG business and oil and gas assets. In March 2014, Apache completed the sale of all of its operations in Argentina. Results of operations and cash flows for the divested Australia assets and Argentina operations are reflected as discontinued operations in the Company’s financial statements for all periods presented. Significant policies are discussed below. Recast Financial Information for Change in Accounting Principle In the second quarter of 2016, Apache voluntarily changed its method of accounting for its oil and gas exploration and development activities from the full cost method to the successful efforts method of accounting. The financial information for prior periods has been recast to reflect retrospective application of the successful efforts method, as prescribed by the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 932 “Extractive Activities—Oil and Gas.” Although the full cost method of accounting for oil and gas exploration and development activities continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the U.S. Securities and Exchange Commission (SEC) and is more widely used in the industry such that the change will improve comparability of the Company's financial statements to its peers. The Company believes the successful efforts method provides a more representational depiction of assets and operating results. The successful efforts method also provides for the Company's investments in oil and gas properties to be assessed for impairment in accordance with ASC 360 "Property, Plant, and Equipment" rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. For more detailed information regarding the effects of the change to the successful efforts method, please refer to Note 2—Change in Accounting Principle. The Company has recast certain historical information for all periods presented, including the Statement of Consolidated Operations, Statement of Consolidated Comprehensive Income, Statement of Consolidated Cash Flows, Consolidated Balance Sheet, Statement of Consolidated Changes in Equity, and related information in Notes 1, 2, 3, 4, 6, 7, 8, 9, 12, 13, 15, 16, 17, and 18. In addition , the Company retrospectively adopted a new accounting standard update for all periods presented which requires debt issuance costs to be presented as a direct deduction from the carrying value of the associated debt liability, consistent with debt discounts. For more information regarding this update, please refer to Note 8—Debt and Financing Costs. Principles of Consolidation The accompanying consolidated financial statements include the accounts of Apache and its subsidiaries after elimination of intercompany balances and transactions. The Company’s undivided interests in oil and gas exploration and production ventures and partnerships are proportionately consolidated. The Company consolidates all other investments in which, either through direct or indirect ownership, Apache has more than a 50 percent voting interest or controls the financial and operating decisions. Noncontrolling interests represent third-party ownership in the net assets of a consolidated Apache subsidiary and are reflected separately in the Company’s financial statements. Investments in which Apache holds less than 50 percent of the voting interest are typically accounted for under the equity method of accounting, with the balance recorded as a component of “Deferred charges and other” in Apache’s consolidated balance sheet and results of operations recorded as a component of “Other” under “Revenues and Other” in the Company’s statement of consolidated operations. Use of Estimates Preparation of financial statements in conformity with GAAP and disclosure of contingent assets and liabilities requires management to make estimates and assumptions that affect reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Apache evaluates its estimates and assumptions on a regular basis. Actual results may differ from these estimates and assumptions used in preparation of its financial statements and changes in these estimates are recorded when known. Significant estimates with regard to these financial statements include the fair value determination of acquired assets and liabilities and assets held for sale at year-end (see Note 3—Acquisitions and Divestitures), the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom (see Note 16—Supplemental Oil and Gas Disclosures), the assessment of asset retirement obligations (see Note 7—Asset Retirement Obligation), the estimates of fair value for long-lived assets and goodwill (see “Fair Value Measurements,” “Property and Equipment,” and “Goodwill” sections in this Note 1 below), and the estimate of income taxes (see Note 9—Income Taxes). Fair Value Measurements Certain assets and liabilities are reported at fair value on a recurring basis in Apache’s consolidated balance sheet. ASC 820-10-35 provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consist of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments. Level 3 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority. The valuation techniques that may be used to measure fair value include a market approach, an income approach, and a cost approach. A market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. An income approach uses valuation techniques to convert future amounts to a single present amount based on current market expectations, including present value techniques, option-pricing models, and the excess earnings method. The cost approach is based on the amount that currently would be required to replace the service capacity of an asset (replacement cost). Recurring fair value measurements are presented in further detail in Note 8—Debt and Note 11—Retirement and Deferred Compensation Plans. Apache also uses fair value measurements on a nonrecurring basis when certain qualitative assessments of its assets indicate a potential impairment. For the year ended December 31, 2015, the Company recorded asset impairments totaling $11.9 billion in connection with fair value assessments in the current low commodity price environment. Impairments totaling $11.6 billion were recorded for certain property and equipment, which were written down to their fair values. These impairments are discussed in further detail below in “Property and Equipment.” Also in 2015, the Company recorded $163 million for the impairment of goodwill, $148 million for the impairment of an equity method investment sold in the fourth quarter, and $55 million for inventory write-downs. For a discussion of the equity method investment impairment, see Note 3—Acquisitions and Divestitures. For the year ended December 31, 2014, the Company recorded asset impairments totaling $9.1 billion in connection with fair value assessments, including $8.0 billion for property and equipment, $347 million for the impairment of goodwill, $655 million for the impairment of assets held for sale, and $32 million for inventory write-downs. The Company also recorded $833 million in impairments related to the sale of the Company's Australian assets and an additional $271 million in impairment of proved properties and inventory in Australia. These impairments are classified as discontinued operations in 2014. For discussion of these impairments, see “Property and Equipment” and “Goodwill” below and Note 3—Acquisitions and Divestitures. For the year ended December 31, 2013, the Company recorded asset impairments totaling $1.8 billion for property and equipment in connection with fair value assessments. Cash Equivalents The Company considers all highly liquid short-term investments with a maturity of three months or less at the time of purchase to be cash equivalents. These investments are carried at cost, which approximates fair value. As of December 31, 2015 and 2014, Apache had $1.5 billion and $679 million , respectively, of cash and cash equivalents. Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable are stated at the historical carrying amount net of write-offs and an allowance for doubtful accounts. The carrying amount of Apache’s accounts receivable approximates fair value because of the short-term nature of the instruments. The Company routinely assesses the collectability of all material trade and other receivables. Many of Apache’s receivables are from joint interest owners on properties Apache operates. The Company may have the ability to withhold future revenue disbursements to recover any non-payment of these joint interest billings. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. As of December 31, 2015, 2014, and 2013, the Company had an allowance for doubtful accounts of $103 million , $98 million , and $78 million , respectively. During 2015, Apache’s allowance for doubtful accounts increased $5 million , reflecting additional provisions for the year of $40 million , partially offset by $35 million for uncollectible accounts written off net of recoveries. Inventories Inventories consist principally of tubular goods and equipment, stated at weighted-average cost, and oil produced but not sold, stated at the lower of cost or market. Property and Equipment The carrying value of Apache’s property and equipment represents the cost incurred to acquire the property and equipment, including capitalized interest, net of any impairments. For business combinations, property and equipment cost is based on the fair values at the acquisition date. Oil and Gas Property The Company follows the successful efforts method of accounting for its oil and gas property. Under this method of accounting, exploration costs such as exploratory dry holes, exploratory geological and geophysical costs, delay rentals, unproved impairments, and exploration overhead are expensed as incurred. All costs related to production, general corporate overhead, and similar activities are expensed as incurred. If an exploratory well provides evidence to justify potential development of reserves, drilling costs associated with the well are initially capitalized, or suspended, pending a determination as to whether a commercially sufficient quantity of proved reserves can be attributed to the area as a result of drilling. This determination may take longer than one year in certain areas depending on, among other things, the amount of hydrocarbons discovered, the outcome of planned geological and engineering studies, the need for additional appraisal drilling activities to determine whether the discovery is sufficient to support an economic development plan, and government sanctioning of development activities in certain international locations. At the end of each quarter, management reviews the status of all suspended exploratory well costs in light of ongoing exploration activities; in particular, whether the Company is making sufficient progress in its ongoing exploration and appraisal efforts or, in the case of discoveries requiring government sanctioning, whether development negotiations are underway and proceeding as planned. If management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed. Acquisition costs of unproved properties are assessed for impairment at least annually and are transferred to proved oil and gas properties to the extent the costs are associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment based on the Company’s current exploration plans. Unproved oil and gas properties with individually insignificant lease acquisition costs are amortized on a group basis over the average lease term at rates that provide for full amortization of unsuccessful leases upon lease expiration or abandonment. Costs of expired or abandoned leases are charged to exploration expense, while costs of productive leases are transferred to proved oil and gas properties. Costs of maintaining and retaining unproved properties, as well as amortization of individually insignificant leases and impairment of unsuccessful leases, are included in exploration costs in the statement of consolidated operations. Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of crude oil and natural gas, are capitalized. Depreciation of the cost of proved oil and gas properties is calculated using the unit-of-production (UOP) method. The UOP calculation multiplies the percentage of estimated proved reserves produced each quarter by the carrying value of those reserves. The reserve base used to calculate depreciation for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are included in the depreciable cost. Oil and gas properties are grouped for depreciation in accordance with ASC 932 “Extractive Activities - Oil and Gas.” The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field. When circumstances indicate that proved oil and gas properties may be impaired, the Company compares unamortized capitalized costs to the expected undiscounted pre-tax future cash flows for the associated assets grouped at the lowest level for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows, based on Apache’s estimate of future crude oil and natural gas prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 “Fair Value Measurement.” If applicable, the Company utilizes accepted bids as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future production volumes, commodity prices, operating costs, and capital investment plans, considering all available information at the date of review. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Apache has classified these fair value measurements as Level 3 in the fair value hierarchy. The following table represents non-cash impairments of the carrying value of the Company’s proved and unproved property and equipment for 2015, 2014 and 2013: For the Year Ended December 31, 2015 2014 2013 (In millions) Oil and Gas Property: Proved $ 7,389 $ 6,068 $ 1,443 Unproved 2,462 1,976 319 The fair values of the impaired proved properties as of the most recent date of impairment were $3.9 billion , $4.8 billion , and $3.8 billion for 2015, 2014, and 2013, respectively. On the consolidated statement of operations, unproved impairments are recorded in exploration expense, and proved impairments are recorded in impairments. Gains and losses on significant divestitures are recognized in the statement of consolidated operations. See Note 3—Acquisitions and Divestitures for more detail. Gathering, Transmission, and Processing Facilities GTP facilities totaled $1.1 billion and $5.4 billion at December 31, 2015 and 2014, respectively, with accumulated depreciation for these assets totaling $160 million and $1.7 billion for the respective periods. GTP facilities are depreciated on a straight-line basis over the estimated useful lives of the assets. The estimation of useful life takes into consideration anticipated production lives from the fields serviced by the GTP assets, whether Apache-operated or third party, as well as potential development plans by Apache for undeveloped acreage within or in close proximity to those fields. The Company assesses the carrying amount of its GTP facilities whenever events or changes in circumstances indicate that their carrying amount may not be recoverable. If the carrying amount of these facilities is more than the sum of the undiscounted cash flows, an impairment loss is recognized for the excess of the carrying value over its fair value. During 2015, the Company recorded impairments of $1.7 billion on certain GTP assets, including $1.1 billion in Egypt, $555 million in Canada, and $103 million in the U.S., which were written down to their fair values of $306 million in aggregate. The fair values of the impaired assets were determined using an income approach, which considered internal estimates of future throughput volumes, processing rates, and costs. These assumptions were applied to develop future cash flow projections that were then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Apache has classified these non-recurring fair value measurements as Level 3 in the fair value hierarchy. During 2014, the Company recorded impairments of $1.1 billion of its GTP assets related to the sale of Apache’s Wheatstone and Kitimat LNG projects, and the remaining carrying value of those assets was reclassified to “Assets held for sale” on the Company’s consolidated balance sheet as of December 31, 2014. The $430 million impairment of GTP assets related to Apache's Wheatstone LNG project is reflected in discontinued operations in the Company's statement of consolidated operations. No impairments of GTP facilities were recognized during 2013. The costs of GTP facilities retired or otherwise disposed of and associated accumulated depreciation are removed from Apache’s consolidated financial statements, and the resulting gain or loss is reflected in “Gain (loss) on divestitures” under “Revenues and Other” in the Company’s statement of consolidated operations. During 2015, Apache recorded a gain on the sale of GTP facilities totaling $59 million associated with the Company’s divestitures of certain Permian Basin assets. During 2014, the Company recorded a loss totaling $180 million associated with divestitures of certain Anadarko basin and southern Louisiana assets. No gain or loss on the sales of GTP facilities was recognized during 2013. Other Property and Equipment Other property and equipment includes computer software and equipment, buildings, vehicles, furniture and fixtures, land, and other equipment. These assets are depreciated on a straight-line basis over the estimated useful lives of the assets, which range from 3 to 20 years. Accumulated depreciation for these assets totaled $693 million and $673 million at December 31, 2015 and 2014, respectively. Asset Retirement Costs and Obligations The initial estimated asset retirement obligation related to property and equipment is recorded as a liability at its fair value, with an offsetting asset retirement cost recorded as an increase to the associated property and equipment on the consolidated balance sheet. If the fair value of the recorded asset retirement obligation changes, a revision is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from changes in estimated inflation rates, changes in service and equipment costs and changes in the estimated timing of an asset’s retirement. Asset retirement costs are depreciated using a systematic and rational method similar to that used for the associated property and equipment. Accretion expense on the liability is recognized over the estimated productive life of the related assets. Capitalized Interest For significant projects, interest is capitalized as part of the historical cost of developing and constructing assets. Significant oil and gas investments in unproved properties actively being explored, significant exploration and development projects that have not commenced production, significant midstream development activities that are in progress, and investments in equity method affiliates that are undergoing the construction of assets that have not commenced principal operations qualify for interest capitalization. Interest is capitalized until the asset is ready for service. Capitalized interest is determined by multiplying the Company’s weighted-average borrowing cost on debt by the average amount of qualifying costs incurred. Once an asset subject to interest capitalization is completed and placed in service, the associated capitalized interest is expensed through depreciation or impairment. Goodwill Goodwill represents the excess of the purchase price of an entity over the estimated fair value of the assets acquired and liabilities assumed, and it is recorded in "Deferred charges and other" in the Company's consolidated balance sheet. The Company assesses the carrying amount of goodwill by testing for impairment annually and when impairment indicators arise. The impairment test requires allocating goodwill and all other assets and liabilities to assigned reporting units. As of December 31, 2015, Apache assesses each country as a reporting unit. The fair value of each unit is determined and compared to the book value of the reporting unit. If the fair value of the reporting unit is less than the book value, including goodwill, then goodwill is written down to the implied fair value of the goodwill through a charge to expense. In order to determine the fair value of each reporting unit, the Company uses a combination of the income approach and the market approach. The income approach considers management views on current operating measures as well as assumptions pertaining to market forces in the oil and gas industry, such as future production, future commodity prices, and costs. These assumptions are applied to develop future cash flow projections that are then discounted to estimate fair value, using a discount rate similar to those used by the Company in the valuation of acquisitions and divestitures. To assess the reasonableness of its fair value estimate, the Company uses a market approach to compare the fair value to similar businesses whose securities are actively traded in the public market. This requires management to make certain judgments about the selection of comparable companies, recent comparable asset transactions, and transaction premiums. Associated market multiples are applied to various financial metrics of the reporting unit to estimate fair value. Apache has classified this reporting unit estimation as a non-recurring Level 3 fair value measurement. When there is a disposal of a reporting unit or a portion of a reporting unit that constitutes a business, goodwill associated with that business is included in the carrying amount to determine the gain or loss on disposal. The amount of goodwill allocated to the carrying amount of a business can significantly impact the amount of gain or loss recognized on the sale of that business. The amount of goodwill to be included in that carrying amount is based on the relative fair value of the business to be disposed of and the portion of the reporting unit that will be retained. The changes in goodwill in 2014 and 2013 represent amounts allocated to U.S. properties sold in each respective year. The following presents the changes to goodwill for the years ended 2015, 2014, and 2013: United States Canada Egypt North Sea Total (In millions) Goodwill at December 31, 2012 $ 1,016 $ 103 $ 87 $ 83 $ 1,289 Divested (632 ) — — — (632 ) Acquired — — — 80 80 Impairments — — — — — Goodwill at December 31, 2013 384 103 87 163 737 Divested (140 ) — — — (140 ) Impairments (244 ) (103 ) — — (347 ) Goodwill at December 31, 2014 — — 87 163 250 Divested — — — — — Impairments — — — (163 ) (163 ) Goodwill at December 31, 2015 $ — $ — $ 87 $ — $ 87 Reductions in estimated net present value of expected future cash flows from oil and gas properties resulted in implied fair values below the carrying values of Apache’s U.S., North Sea, and Canada reporting units. These goodwill impairments have been recorded in “Impairments” in the Company’s statement of consolidated operations. Accounts Payable Included in accounts payable at December 31, 2015 and 2014, are liabilities of approximately $129 million and $229 million , respectively, representing the amount by which checks issued but not presented to the Company’s banks for collection exceeded balances in applicable bank accounts. Commitments and Contingencies Accruals for loss contingencies arising from claims, assessments, litigation, environmental and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. These accruals are adjusted as additional information becomes available or circumstances change. Revenue Recognition and Imbalances Oil and gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Cash received relating to future revenues is deferred and recognized when all revenue recognition criteria are met. Apache uses the sales method of accounting for gas production imbalances. The volumes of gas sold may differ from the volumes to which Apache is entitled based on its interests in the properties. These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to Apache will not be sufficient to enable the under-produced owner to recoup its entitled share through production. The Company’s recorded liability is generally reflected in other non-current liabilities. No receivables are recorded for those wells where Apache has taken less than its share of production. Gas imbalances are reflected as adjustments to estimates of proved gas reserves and future cash flows in the unaudited supplemental oil and gas disclosures. Apache markets its own North American natural gas production. Since the Company’s production fluctuates because of operational issues, it is occasionally necessary to purchase third-party oil and gas to fulfill sales obligations and commitments. The costs of third-party oil and gas purchases totaled $105 million , $70 million , and $39 million , for 2015, 2014, and 2013, respectively, which were netted against the related sales proceeds . The Company’s Egyptian operations are conducted pursuant to production sharing contracts under which contractor partners pay all operating and capital costs for exploring and developing the concessions. A percentage of the production, generally up to 40 percent , is available to contractor partners to recover these operating and capital costs over contractually defined periods. Cost recovery is reflected in revenue. The balance of the production is split among the contractor partners and the Egyptian General Petroleum Corporation (EGPC) on a contractually defined basis. Derivative Instruments and Hedging Activities Apache periodically enters into derivative contracts to manage its exposure to commodity price risk. These derivative contracts, which are generally placed with major financial institutions, may take the form of forward contracts, futures contracts, swaps, or options. The oil and gas reference prices upon which the commodity derivative contracts are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company for its oil and gas production. As of December 31, 2015, Apache had no open derivative positions. When applicable, Apache records all derivative instruments, other than those that meet the normal purchases and sales exception, on the balance sheet as either an asset or liability measured at fair value. Changes in fair value are recognized currently in earnings unless specific hedge accounting criteria are met. Gains and losses from the change in fair value of derivative instruments that do not qualify for hedge accounting are reported in current-period income as “Derivative instrument gains (losses), net” under “Revenues and Other” in the statement of consolidated operations. Hedge accounting treatment allows unrealized gains and losses on cash flow hedges to be deferred in other comprehensive income. Realized gains and losses from the Company’s oil and gas cash flow hedges, including terminated contracts, are generally recognized in oil and gas production revenues when the forecasted transaction occurs. If at any time the likelihood of occurrence of a hedged forecasted transaction ceases to be “probable,” hedge accounting treatment will cease on a prospective basis, and all future changes in the fair value of the derivative will be recognized directly in earnings. Amounts recorded in other comprehensive income prior to the change in the likelihood of occurrence of the forecasted transaction will remain in other comprehensive income until such time as the forecasted transaction impacts earnings. If it becomes probable that the original forecasted production will not occur, then the derivative gain or loss would be reclassified from accumulated other comprehensive income into earnings immediately. Hedge effectiveness is measured at least quarterly based on the relative changes in fair value between the derivative contract and the hedged item over time, and any ineffectiveness is immediately reported as “Other” under “Revenues and Other” in the statement of consolidated operations. Income Taxes Apache records deferred tax assets and liabilities to account for the expected future tax consequences of events that have been recognized in the financial statements and tax returns. The Company routinely assesses the ability to realize its deferred tax assets. If the Company concludes that it is more likely than not that some or all of the deferred tax assets will not be realized, the tax asset is reduced by a valuation allowance. Numerous judgments and assumptions are inherent in the determination of future taxable income, including factors such as future operating conditions (particularly as related to prevailing oil and gas prices) and changing tax laws. Apache does not record U.S. deferred income taxes on foreign subsidiaries that are deemed to be permanently reinvested. When such earnings are no longer deemed permanently reinvested, Apache will recognize the appropriate U.S. current or deferred income tax liabilities. For more information, please refer to Note 9—Income Taxes. Foreign Currency Transaction Gains and Losses The U.S. dollar is the functional currency for each of Apache’s international operations. The functional currency is determined country-by-country based on relevant facts and circumstances of the cash flows, commodity pricing environment and financing arrang

Change in Accounting Principle

Change in Accounting Principle	12 Months Ended
	Dec. 31, 2015
Accounting Changes and Error Corrections [Abstract]
Change in Accounting Principle	CHANGE IN ACCOUNTING PRINCIPLE During the second quarter of 2016, the Company voluntarily changed its method of accounting for oil and gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. In general, under successful efforts, exploration expenditures such as exploratory dry holes, exploratory geological and geophysical costs, delay rentals, unproved impairments, and exploration overhead are charged against earnings as incurred, versus being capitalized under the full cost method of accounting. Successful efforts also provides for the assessment of potential property impairments under ASC 360 by comparing the net carrying value of oil and gas properties with associated projected undiscounted pre-tax future net cash flows. If the expected undiscounted pre-tax future net cash flows are lower than the unamortized capitalized costs, the capitalized cost is reduced to fair value. Under the full cost method of accounting, a write-down would be required if the net carrying value of oil and gas properties exceeds a full cost “ceiling,” using an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months. In addition, gains or losses, if applicable, are generally recognized on the dispositions of oil and gas property and equipment under the successful efforts method, as opposed to an adjustment to the net carrying value of the remaining assets under the full cost method. Apache’s consolidated financial statements have been recast to reflect these differences. The adjustments for the 2014 consolidated balance sheet also include assets classified as held-for-sale under the successful efforts method of accounting. The following tables present the effects of the change to the successful efforts method in the statement of consolidated operations: Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 4,999 $ 108 $ 5,107 Natural gas revenues 1,157 19 1,176 NGL revenues 227 — 227 Oil and gas production revenues 6,383 127 6,510 Other (76 ) 174 98 Gain (loss) on divestiture 59 222 281 Exploration — 2,771 2,771 General and administrative 377 3 380 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 3,531 (555 ) 2,976 Additional 25,517 (25,517 ) — Impairments 1,920 7,552 9,472 Financing costs, net 299 212 511 Current income tax provision 309 126 435 Deferred income tax provision (benefit) (5,778 ) 4,333 (1,445 ) NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (22,757 ) 11,598 (11,159 ) Net loss attributable to noncontrolling interest (409 ) 94 (315 ) NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS (22,348 ) 11,504 (10,844 ) Net income (loss) from discontinued operations, net of tax (771 ) 1,263 492 NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS (23,119 ) 12,767 (10,352 ) Per Common Share Basic net loss from continuing operations per share $ (59.16 ) $ 30.46 $ (28.70 ) Basic net income (loss) from discontinued operations per share (2.04 ) 3.34 1.30 Basic net loss per share $ (61.20 ) $ 33.80 $ (27.40 ) Diluted net loss from continuing operations per share $ (59.16 ) $ 30.46 $ (28.70 ) Diluted net income (loss) from discontinued operations per share (2.04 ) 3.34 1.30 Diluted net loss per share $ (61.20 ) $ 33.80 $ (27.40 ) Other Comprehensive Income Pension and postretirement benefit plan, net of tax $ — $ (3 ) $ (3 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK (23,119 ) 12,764 (10,355 ) Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 10,040 $ 70 $ 10,110 Natural gas revenues 1,983 34 2,017 NGL revenues 668 — 668 Oil and gas production revenues 12,691 104 12,795 Other 290 (5 ) 285 Gain (loss) on divestiture (180 ) (1,428 ) (1,608 ) Exploration — 2,499 2,499 General and administrative 451 2 453 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 4,388 (193 ) 4,195 Additional 5,001 (5,001 ) — Impairments 1,919 5,183 7,102 Financing costs, net 211 202 413 Current income tax provision 1,177 104 1,281 Deferred income tax provision (benefit) (514 ) (1,285 ) (1,799 ) NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (3,472 ) (2,840 ) (6,312 ) Net income attributable to noncontrolling interest 343 (2 ) 341 NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS (3,815 ) (2,838 ) (6,653 ) Net loss from discontinued operations, net of tax (1,588 ) (119 ) (1,707 ) NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS (5,403 ) (2,957 ) (8,360 ) Per Common Share Basic net loss from continuing operations per share $ (9.93 ) $ (7.39 ) $ (17.32 ) Basic net loss from discontinued operations per share (4.13 ) (0.31 ) (4.44 ) Basic net loss per share $ (14.06 ) $ (7.70 ) $ (21.76 ) Diluted net loss from continuing operations per share $ (9.93 ) $ (7.39 ) $ (17.32 ) Diluted net loss from discontinued operations per share (4.13 ) (0.31 ) (4.44 ) Diluted net loss per share $ (14.06 ) $ (7.70 ) $ (21.76 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (5,404 ) $ (2,957 ) $ (8,361 ) Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2013 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 11,853 $ 17 $ 11,870 Natural gas revenues 2,266 37 2,303 NGL revenues 652 — 652 Oil and gas production revenues 14,771 54 14,825 Other (333 ) 18 (315 ) Gain (loss) on divestiture — (1,231 ) (1,231 ) Exploration — 942 942 General and administrative 481 10 491 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 4,534 171 4,705 Additional 995 (995 ) — Other assets 337 15 352 Impairments — 1,443 1,443 Financing costs, net 229 216 445 Current income tax provision 1,619 54 1,673 Deferred income tax provision (benefit) 309 (1,041 ) (732 ) NET INCOME FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST 1,980 (1,974 ) 6 NET INCOME (LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS 1,880 (1,974 ) (94 ) Net income from discontinued operations, net of tax 308 130 438 NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS 2,188 (1,844 ) 344 Per Common Share Basic net income (loss) from continuing operations per share $ 4.75 $ (4.99 ) $ (0.24 ) Basic net income from discontinued operations per share 0.78 0.33 1.11 Basic net loss per share $ 5.53 $ (4.66 ) $ 0.87 Diluted net income (loss) from continuing operations per share $ 4.74 $ (4.98 ) $ (0.24 ) Diluted net income from discontinued operations per share 0.76 0.35 1.11 Diluted net income per share $ 5.50 $ (4.63 ) $ 0.87 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 2,204 $ (1,844 ) $ 360 The following tables present the effects of the change to the successful efforts method in the statement of consolidated cash flows: Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ (23,528 ) $ 12,861 $ (10,667 ) Loss (income) from discontinued operations 771 (1,263 ) (492 ) Loss (gain) on divestitures, net (59 ) (222 ) (281 ) Exploratory dry hole expense and unproved leasehold impairments — 2,595 2,595 Depreciation, depletion, and amortization 29,372 (26,072 ) 3,300 Impairments 1,920 7,552 9,472 Other noncash items, net 161 (154 ) 7 Provision for (benefit from) deferred income taxes (5,778 ) 4,333 (1,445 ) Changes in operating assets and liabilities (170 ) 90 (80 ) Net cash provided by operating activities - continuing operations 2,834 (280 ) 2,554 Net cash provided by operating activities - discontinued operations 150 (37 ) 113 Additions to oil and gas property (4,578 ) 370 (4,208 ) Net cash used in investing activities - continuing operations (3,659 ) 370 (3,289 ) Net cash provided by investing activities - discontinued operations 4,335 37 4,372 NET INCREASE (DECREASE) IN CASH 698 90 788 BEGINNING CASH BALANCE 769 (90 ) 679 ENDING CASH BALANCE 1,467 — 1,467 Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ (5,060 ) $ (2,959 ) $ (8,019 ) Loss (income) from discontinued operations 1,588 119 1,707 Loss (gain) on divestitures, net 180 1,428 1,608 Exploratory dry hole expense and unproved leasehold impairments — 2,294 2,294 Depreciation, depletion, and amortization 9,720 (5,194 ) 4,526 Impairments 1,919 5,183 7,102 Provision for (benefit from) deferred income taxes (514 ) (1,285 ) (1,799 ) Changes in operating assets and liabilities (239 ) (90 ) (329 ) Net cash provided by operating activities - continuing operations 7,517 (504 ) 7,013 Net cash provided by operating activities - discontinued operations 944 — 944 Additions to oil and gas property (9,022 ) 414 (8,608 ) Net cash used in investing activities - continuing operations (8,585 ) 414 (8,171 ) Net cash used in investing activities - discontinued operations (219 ) — (219 ) NET INCREASE (DECREASE) IN CASH (1,137 ) (90 ) (1,227 ) BEGINNING CASH BALANCE 1,906 — 1,906 ENDING CASH BALANCE 769 (90 ) 679 Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2013 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ 2,288 $ (1,844 ) $ 444 Loss (income) from discontinued operations (308 ) (130 ) (438 ) Loss (gain) on divestitures, net — 1,231 1,231 Exploratory dry hole expense and unproved leasehold impairments — 729 729 Depreciation, depletion, and amortization 5,866 (809 ) 5,057 Impairments — 1,443 1,443 Provision for (benefit from) deferred income taxes 309 (1,041 ) (732 ) Net cash provided by operating activities - continuing operations 8,685 (421 ) 8,264 Net cash provided by operating activities - discontinued operations 1,150 14 1,164 Additions to oil and gas property (8,663 ) 421 (8,242 ) Net cash used in investing activities - continuing operations (5,256 ) 421 (4,835 ) Net cash used in investing activities - discontinued operations (1,860 ) (14 ) (1,874 ) NET INCREASE (DECREASE) IN CASH 1,746 — 1,746 BEGINNING CASH BALANCE 160 — 160 ENDING CASH BALANCE 1,906 — 1,906 The following tables present the effects of the change to the successful efforts method in the consolidated balance sheet: Changes to the Consolidated Balance Sheet December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) PROPERTY AND EQUIPMENT: Property and equipment - cost $ 93,825 $ (47,675 ) $ 46,150 Less: Accumulated depreciation, depletion, and amortization (79,706 ) 54,394 (25,312 ) PROPERTY AND EQUIPMENT, NET 14,119 6,719 20,838 TOTAL ASSETS 18,781 6,719 25,500 Income taxes 1,072 1,457 2,529 Paid-in capital 12,467 152 12,619 Accumulated deficit (1) (7,153 ) 5,173 (1,980 ) Accumulated other comprehensive loss (116 ) (3 ) (119 ) Noncontrolling interest 1,662 (60 ) 1,602 TOTAL EQUITY 4,228 5,262 9,490 Changes to the Consolidated Balance Sheet December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Cash and cash equivalents $ 769 $ (90 ) $ 679 Receivables, net of allowance 2,024 (5 ) 2,019 Inventories 708 (27 ) 681 Drilling advances 388 (105 ) 283 Current assets held for sale 1,628 1,753 3,381 Deferred tax asset 769 121 890 PROPERTY AND EQUIPMENT: Property and equipment - cost 103,458 (42,000 ) 61,458 Less: Accumulated depreciation, depletion, and amortization (55,382 ) 28,569 (26,813 ) PROPERTY AND EQUIPMENT, NET 48,076 (13,431 ) 34,645 Deferred charges and other 1,394 163 1,557 TOTAL ASSETS 55,885 (11,621 ) 44,264 Accounts payable 1,210 (100 ) 1,110 Current liabilities held for sale 19 409 428 Other current liabilities 2,435 (195 ) 2,240 Income taxes 9,499 (4,006 ) 5,493 Noncurrent asset retirement obligations 3,048 (133 ) 2,915 Paid-in capital 12,438 152 12,590 Retained earnings (1) 16,249 (7,594 ) 8,655 Noncontrolling interest 2,200 (154 ) 2,046 TOTAL EQUITY 28,137 (7,596 ) 20,541 *In conjunction with recasting the financial information for the adoption of the successful efforts method of accounting, we corrected certain immaterial errors in the North Sea pertaining to the improper calculation of deferred tax liabilities associated with capitalized interest under the full cost method. (1) The cumulative effect of the change to the successful efforts method on retained earnings (accumulated deficit) as of January 1, 2013 was a decrease of $2.8 billion .

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Acquisitions and Divestitures	Activity Yara Pilbara Holdings Pty Limited Sale In October 2015, Apache sold its 49 percent interest in Yara Pilbara Holdings Pty Limited (YPHPL) for total cash proceeds of $391 million . The investment in YPHPL was accounted for under the equity method of accounting, with the balance recorded as a component of “Deferred charges and other” in Apache’s consolidated balance sheet and the results of operations recorded as a component of “Other” under “Revenue and other” in the Company’s statement of consolidated operations. As of September 30, 2015, Apache recognized an impairment of $148 million on the YPHPL equity investment based on negotiated sales proceeds. No additional gain or loss was recorded upon completion of the sale. Canada Divestiture In April 2015, Apache completed the sale of its 50 percent interest in the Kitimat LNG project and upstream acreage in the Horn River and Liard natural gas basins to Woodside Petroleum Limited (Woodside). Proceeds at closing were $854 million , of which approximately $344 million was associated with LNG assets and $510 million was associated with upstream assets. For additional details related to post-closing adjustments, please see Note 10—Commitments and Contingencies. The Kitimat LNG assets classified as held for sale on the consolidated balance sheet as of December 31, 2014 were impaired $655 million in the fourth quarter of 2014. Apache recognized a $146 million gain on the sale of the upstream assets upon completion of the sale. Australia Divestitures Woodside Sale In April 2015, Apache completed the sale of the Wheatstone LNG project and associated upstream oil and gas assets to Woodside. Proceeds at closing were $2.8 billion , of which approximately $1.4 billion was associated with LNG assets and $1.4 billion was associated with the upstream assets. For additional details related to post-closing adjustments, please see Note 10—Commitments and Contingencies. The Wheatstone LNG assets and associated upstream assets were impaired $833 million in the fourth quarter of 2014 and classified as held for sale on the consolidated balance sheet as of December 31, 2014. An additional impairment of approximately $49 million was recognized in the first quarter of 2015. No additional gain or loss was recognized on the ultimate disposal of the LNG project and upstream assets. Consortium Sale In June 2015, Apache completed the sale of its Australian subsidiary Apache Energy Limited (AEL) to a consortium of private equity funds managed by Macquarie Capital Group Limited and Brookfield Asset Management Inc. Total proceeds of $1.9 billion include customary, post-closing adjustments for the period between the effective date, October 1, 2014, and closing. A loss of approximately $139 million was recognized for the sale of AEL. Upon closing of the sale of substantially all Australian operations, the associated results of operations for the divested Australian assets and the losses on disposal were classified as discontinued operations in the Company’s financial statements for all periods presented. The carrying amounts of the major classes of consolidated assets and liabilities associated with the Australia dispositions were as follows: December 31, 2014 (In millions) ASSETS Current assets held for sale $ 3,019 Other current assets 590 Oil and gas assets, net 1,613 GTP and other assets, net 877 Total assets $ 6,099 LIABILITIES Current liabilities held for sale $ 321 Other current liabilities 318 Asset retirement obligations 466 Non-current deferred tax liability 329 Other long-term liabilities 33 Total liabilities $ 1,467 Sales and other operating revenues and loss from discontinued operations related to the Australia dispositions were as follows: For the Year Ended December 31, 2015 2014 2013 (In millions) Revenues and other from discontinued operations $ 288 $ 1,050 $ 1,121 Impairment on Woodside sale $ (49 ) $ (833 ) $ — Loss on Consortium sale (139 ) — — Income (loss) from divested Australian operations 28 (12 ) 550 Income tax benefit (expense) 652 (231 ) (22 ) Income (loss) from Australian discontinued operations, net of tax $ 492 $ (1,076 ) $ 528 2014 Activity Anadarko Basin and Southern Louisiana Divestitures In December 2014, Apache completed the sale of certain Anadarko basin and non-core southern Louisiana oil and gas assets for approximately $1.3 billion in two separate transactions. In the Anadarko basin, Apache sold approximately 115,000 net acres in Wheeler County, Texas, and western Oklahoma. In southern Louisiana, Apache sold its working interest in approximately 90,000 net acres. The effective date of both of these transactions is October 1, 2014. Apache recognized a net $823 million loss on these transactions, of which approximately $10 million was associated with goodwill and approximately $180 million was associated with GTP facilities. Gulf of Mexico Deepwater Divestiture On June 30, 2014, Apache completed the sale of non-operated interests in the Lucius and Heidelberg development projects and 11 primary-term deepwater exploration blocks in the Gulf of Mexico for $1.4 billion . The effective date of the transaction was May 1, 2014 . Apache recognized a $332 million loss as a result of the transaction, of which approximately $130 million was associated with goodwill. Canada Divestiture On April 30, 2014, Apache completed the sale of primarily dry gas producing hydrocarbon assets in the Deep Basin area of western Alberta and British Columbia, Canada, for $374 million . The assets comprise 328,400 net acres in the Ojay, Noel, and Wapiti areas. Apache retained 100 percent of its working interest in horizons below the Cretaceous in the Wapiti area, including rights to the liquids-rich Montney and other deeper horizons. The effective date of the transaction was January 1, 2014 . Apache recognized a $237 million loss related to the sale of the assets. Argentina Divestiture On March 12, 2014, Apache’s subsidiaries completed the sale of all of the Company’s operations in Argentina to YPF Sociedad Anónima for cash consideration of $800 million (subject to customary closing adjustments) plus the assumption of $52 million of bank debt as of June 30, 2013 . The results of operations related to Argentina have been classified as discontinued operations in all periods presented. Sales and other operating revenues and loss from discontinued operations related to the Argentina disposition were as follows: For the Year Ended December 31, 2015 2014 2013 (In millions) Revenues and other from discontinued operations $ — $ 87 $ 494 Loss from Argentina divestiture — (654 ) — Income (loss) from operations in Argentina — (1 ) (90 ) Income tax benefit — 23 — Income (loss) from discontinued operations, net of tax $ — $ (632 ) $ (90 ) 2013 Activity Egypt Partnership On November 14, 2013, Apache completed the sale of a one-third minority participation in its Egypt oil and gas business to a subsidiary of Sinopec International Petroleum Exploration and Production Corporation (Sinopec). Apache received cash consideration of $2.95 billion after customary closing adjustments. Apache continues to operate its Egypt upstream oil and gas business. Apache recorded $1.8 billion of the proceeds as a non-controlling interest, which is reflected as a separate component of equity in the Company’s consolidated balance sheet. This represents one-third of Apache’s net book value of its Egypt holdings at the time of the transaction. Gulf of Mexico Shelf Divestiture On September 30, 2013, Apache completed the sale of its Gulf of Mexico Shelf operations and properties to Fieldwood Energy LLC (Fieldwood), an affiliate of Riverstone Holdings. Under the terms of the agreement, Apache received cash consideration of $3.7 billion , and Fieldwood assumed $1.5 billion of discounted asset abandonment liabilities. Additionally, Apache retained 50 percent of its ownership interest in all exploration blocks and in horizons below production in developed blocks. The effective date of the agreement was July 1, 2013 . Apache recognized a $1.6 billion loss as a result of this transaction, of which approximately $632 million was associated with goodwill. Canada LNG Project In February 2013, Apache completed a transaction with Chevron Canada Limited (Chevron Canada) under which each company became a 50 percent owner of the Kitimat LNG plant, the Pacific Trail Pipelines Limited Partnership (PTP), and 644,000 gross undeveloped acres in the Horn River and Liard basins. Under the terms of the transaction, Apache acquired additional interest in the LNG plant, PTP, and other related assets from Chevron, and Chevron separately purchased interests in Apache's undeveloped acreage and associated upstream assets. Apache received a net payment from the transaction of $396 million after post-closing adjustments. Proceeds associated with the divested undeveloped acreage and upstream assets were approximately $644 million , and the Company recognized a gain of $398 million . Leasehold and Property Acquisitions Apache completed $367 million , $1.5 billion , and $429 million of leasehold and property acquisitions during 2015, 2014, and 2013, respectively, substantially increasing its drilling opportunities in key focus areas in North America including the Eagle Ford and Canyon Lime plays. Transaction, Reorganization, and Separation Apache recorded $132 million , $67 million , and $33 million of expenses during 2015, 2014, and 2013, respectively, primarily related to various transactions, company reorganization, and employee separation. Divestiture of Other Oil and Gas Properties Apache recorded $268 million , $96 million , and $307 million of proceeds from the divestiture of other oil and gas properties during 2015, 2014, and 2013, respectively. An associated $135 million of gain, $216 million of loss, and $3 million of loss was recorded in 2015, 2014, and 2013, respectively.

Capitalized Exploratory Well Co

Capitalized Exploratory Well Costs	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Capitalized Exploratory Well Costs	CAPITALIZED EXPLORATORY WELL COSTS The following summarizes the changes in capitalized exploratory well costs for each of the last three years ended December 31, 2015 , 2014 , and 2013 . Additions pending the determination of proved reserves excludes amounts capitalized and subsequently charged to expense within the same year. 2015 2014 2013 (In millions) Balance at January 1 $ 849 $ 630 $ 546 Additions pending determination of proved reserves 382 622 549 Divestitures and other (557 ) (54 ) (136 ) Reclassifications to proved properties (369 ) (207 ) (244 ) Charged to exploration expense (60 ) (142 ) (85 ) Balance at December 31 (1) $ 245 $ 849 $ 630 (1) Includes $49 million of assets that were held for sale in Australia at December 31, 2014. The following provides an aging of capitalized exploratory well costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year since the completion of drilling: 2015 2014 2013 (In millions) Exploratory well costs capitalized for a period of one year or less $ 184 $ 504 $ 350 Exploratory well costs capitalized for a period greater than one year 61 345 280 Balance at December 31 (1) $ 245 $ 849 $ 630 Number of projects with exploratory well costs capitalized for a period greater than one year 2 18 30 (1) Includes $49 million of assets that were held for sale in Australia at December 31, 2014. The following summarizes a further aging by geographic area of those exploratory well costs that have been capitalized for a period greater than one year since the completion of drilling at December 31, 2015 : 2012 and Total 2014 2013 Prior North Sea $ 61 $ 3 $ — $ 58 $ 61 $ 3 $ — $ 58 Projects with suspended exploratory well costs capitalized for a period greater than one year since the completion of drilling are those identified by management as exhibiting sufficient quantities of hydrocarbons to justify potential development. Management is actively pursuing efforts to assess whether reserves can be attributed to these projects. Suspended exploratory well costs capitalized for a period greater than one year since the completion of drilling at December 31, 2015, primarily relate to the Aviat discovery in the North Sea. The projects associated with the Aviat discovery are comprised of exploration and appraisal drilling activities. The suspended exploratory well costs are pending as additional costs are being incurred to execute a development plan designed to deliver fuel gas to the Forties field, substantially reducing operating costs and extending field life by replacing diesel fuel usage.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Objectives and Strategies The Company is exposed to fluctuations in crude oil and natural gas prices on the majority of its worldwide production. Apache manages the variability in its cash flows by occasionally entering into derivative transactions on a portion of its crude oil and natural gas production. When appropriate, the Company utilizes various types of derivative financial instruments, including swaps and options, to manage fluctuations in cash flows resulting from changes in commodity prices. As of December 31, 2015, Apache had no open commodity derivative positions. Derivative Activity Recorded in the Statement of Consolidated Operations The following table summarizes the effect of derivative instruments on the Company’s statement of consolidated operations: Gain (Loss) on Derivatives Recognized in Income For the Year Ended December 31, 2015 2014 2013 (In millions) Loss on cash flow hedges reclassified from accumulated other comprehensive loss Oil and Gas Production Revenues $ — $ — $ (16 ) Loss for ineffectiveness on cash flow hedges Revenues and Other: Other — — (1 ) Derivatives not designated as cash flow hedges: Realized loss — (16 ) (178 ) Unrealized gain (loss) — 300 (221 ) Gain (loss) on derivatives not designated as cash flow hedges Revenues and Other: Other $ — $ 284 $ (399 ) Unrealized gains and losses for derivative activity recorded in the statement of consolidated operations is reflected in the statement of consolidated cash flows as a component of “Other” in “Adjustments to reconcile net income (loss) to net cash provided by operating activities.”

Other Current Liabilities

Other Current Liabilities	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Other Current Liabilities	OTHER CURRENT LIABILITIES The following table provides detail of the Company’s other current liabilities at December 31, 2015 and 2014: December 31, 2015 2014 (In millions) Accrued operating expenses $ 139 $ 154 Accrued exploration and development 637 1,425 Accrued compensation and benefits 166 204 Accrued interest 144 160 Accrued income taxes 47 54 Current asset retirement obligation 36 37 Current debt 1 — Other 53 206 Total Other current liabilities $ 1,223 $ 2,240

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	ASSET RETIREMENT OBLIGATION The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the years ended December 31, 2015 and 2014: 2015 2014 (In millions) Asset retirement obligation at beginning of year $ 2,952 $ 3,222 Liabilities incurred 68 171 Liabilities divested (490 ) (471 ) Liabilities settled (90 ) (146 ) Accretion expense 158 181 Revisions in estimated liabilities — 128 Liabilities held for sale (1) — (133 ) Asset retirement obligation at end of year 2,598 2,952 Less current portion (36 ) (37 ) Asset retirement obligation, long-term $ 2,562 $ 2,915 (1) As of December 31, 2014, the Company classified $133 million of ARO related to liabilities held for sale on the consolidated balance sheet. The sale was completed in the second quarter of 2015. The ARO liability reflects the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with Apache’s oil and gas properties. The Company utilizes current retirement costs to estimate the expected cash outflows for retirement obligations. The Company estimates the ultimate productive life of the properties, a risk-adjusted discount rate, and an inflation factor in order to determine the current present value of this obligation. To the extent future revisions to these assumptions impact the present value of the existing ARO liability, a corresponding adjustment is made to the oil and gas property balance. Accretion expense for 2015 and 2014 includes discontinued operations of $13 million and $27 million , respectively, which are included in “Net income (loss) from discontinued operations, net of tax” in the statement of consolidated operations. During 2015 and 2014, the Company recorded $68 million and $171 million , respectively, in abandonment liabilities resulting from Apache’s active exploration and development capital program. Liabilities settled primarily relate to individual properties, platforms, and facilities plugged and abandoned during the period.

Debt

Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Debt	DEBT Overview All of the Company’s debt is senior unsecured debt and has equal priority with respect to the payment of both principal and interest. The indentures for the notes described below place certain restrictions on the Company, including limits on Apache’s ability to incur debt secured by certain liens and its ability to enter into certain sale and leaseback transactions. Upon certain changes in control, all of these debt instruments would be subject to mandatory repurchase, at the option of the holders. None of the indentures for the notes contain prepayment obligations in the event of a decline in credit ratings. In September 2015, the Company fully redeemed its $500 million 5.625% notes due in 2017 and its $400 million 1.75% notes due in 2017. The notes were redeemed pursuant to the provisions of each respective note’s indenture. Apache paid the holders an aggregate of $939 million in cash reflecting principal and the premium to par, and an additional $8 million in accrued and unpaid interest. The following table presents the carrying value of the Company’s debt at December 31, 2015 and 2014: December 31, 2015 2014 (In millions) U.S.: Commercial paper $ — $ 1,570 5.625% notes due 2017 (1) — 500 1.75% notes due 2017 (1) — 400 6.9% notes due 2018 (1) 400 400 7.0% notes due 2018 150 150 7.625% notes due 2019 150 150 3.625% notes due 2021 (1) 500 500 3.25% notes due 2022 (1) 919 919 2.625% notes due 2023 (1) 531 531 7.7% notes due 2026 100 100 7.95% notes due 2026 180 180 6.0% notes due 2037 (1) 1,000 1,000 5.1% notes due 2040 (1) 1,500 1,500 5.25% notes due 2042 (1) 500 500 4.75% notes due 2043 (1) 1,500 1,500 4.25% notes due 2044 (1) 800 800 7.375% debentures due 2047 150 150 7.625% debentures due 2096 150 150 8,530 11,000 Subsidiary and other obligations: Notes due in 2016 and 2017 1 1 Apache Finance Canada 7.75% notes due 2029 300 300 301 301 Debt before unamortized discount and debt issuance costs 8,831 11,301 Unamortized discount (53 ) (56 ) Debt issuance costs (61 ) (67 ) Total debt 8,717 11,178 Current maturities (1 ) — Long-term debt $ 8,716 $ 11,178 (1) These notes are redeemable, as a whole or in part, at Apache’s option, subject to a make-whole premium. The remaining notes and debentures are not redeemable. Debt maturities as of December 31, 2015, excluding discounts and debt issuance costs, are as follows: (In millions) 2016 and 2017 $ 1 2018 550 2019 150 Thereafter 8,130 Total Debt, excluding discounts and debt issuance costs $ 8,831 Fair Value The Company’s debt is recorded at the carrying amount, net of unamortized discount, on its consolidated balance sheet. The carrying amount of the Company’s commercial paper and uncommitted credit facilities and overdraft lines approximate fair value because the interest rates are variable and reflective of market rates. Apache uses a market approach to determine the fair value of its fixed-rate debt using estimates provided by an independent investment financial data services firm (a Level 2 fair value measurement). December 31, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Commercial paper $ — $ — $ 1,570 $ 1,570 Notes and debentures 8,717 8,330 9,608 9,944 Total Debt $ 8,717 $ 8,330 $ 11,178 $ 11,514 In April 2015, the FASB issued ASU 2015-03 "Simplifying the Presentation of Debt Issuance Costs," which requires debt issuance costs to be presented as a direct deduction from the carrying value of the associated debt liability. The Company adopted this update in the first quarter of 2016 and applied the changes retrospectively for all periods presented. As of December 31, 2015 and 2014, the Company had debt issuance costs of $61 million and $67 million , respectively, classified as a long-term asset as a component of "deferred charges and other" on the balance sheet that have been netted against "long-term debt" in these financial statements. Money Market and Overdraft Lines of Credit The Company has certain uncommitted money market and overdraft lines of credit that are used from time to time for working capital purposes. As of December 31, 2015 and 2014, there was no outstanding balance on Apache’s lines of credit. Unsecured Committed Bank Credit Facilities In June 2015, the Company entered into a five -year revolving credit facility which matures in June 2020 , subject to Apache’s two , one -year extension options. The facility provides for aggregate commitments of $3.5 billion (including a $750 million letter of credit subfacility), with rights to increase commitments up to an aggregate $4.5 billion . Proceeds from borrowings may be used for general corporate purposes. Apache’s available borrowing capacity under this facility supports its commercial paper program. In connection with entry into the $3.5 billion facility, Apache terminated $5.3 billion in commitments under existing credit facilities. As of December 31, 2015, aggregate available borrowing capacity under this credit facility was $3.5 billion . At the Company’s option, the interest rate per annum for borrowings under the facility is either a base rate, as defined, plus a margin or the London Inter-bank Offered Rate (LIBOR), plus a margin. At December 31, 2015, the margin over LIBOR was 1.0 percent . The Company also pays quarterly a facility fee at per annum rate on total commitments, which at December 31, 2015 was 0.125 percent of the total $3.5 billion in commitments. The margins and the facility fee vary based upon the Company’s senior long-term debt rating. The financial covenants of the credit facility require the Company to maintain an adjusted debt-to-capital ratio of not greater than 60 percent at the end of any fiscal quarter. For purposes of this calculation, capital excludes the effects of non-cash write-downs, impairments, and related charges occurring after June 30, 2015. Negative covenants restrict the ability of the Company and its subsidiaries to create liens securing debt on its hydrocarbon-related assets, with exceptions for liens typically arising in the oil and gas industry, purchase money liens, liens on subsidiary assets located outside of the United States and Canada, and liens arising as a matter of law, such as tax and mechanics’ liens. The Company also may incur liens on assets if debt secured thereby does not exceed 5 percent of the Company’s consolidated assets, or approximately $1.3 billion as of December 31, 2015. Negative covenants also restrict Apache’s ability to merge with another entity unless it is the surviving entity, dispose of substantially all of its assets, and guarantee debt of non-consolidated entities in excess of the stated threshold. There are no clauses in the facility that permit the lenders to accelerate payments or refuse to lend based on unspecified material adverse changes. The credit facility agreement does not have drawdown restrictions or prepayment obligations in the event of a decline in credit ratings. However, the agreement allows the lenders to accelerate payment maturity and terminate lending commitments for nonpayment and other breaches, and if the Company or any of its U.S. or Canadian subsidiaries defaults on other indebtedness in excess of the stated threshold, is insolvent, or has any unpaid, non-appealable judgment against it for payment of money in excess of the stated threshold. Lenders may also accelerate payment maturity and terminate lending commitments if the Company undergoes a specified change in control or any borrower has specified pension plan liabilities in excess of the stated threshold. The Company was in compliance with the terms of the credit facility as of December 31, 2015. In February 2016, Apache entered into a three-year letter of credit facility providing £900 million in commitments, with options to increase commitments to £1.075 billion and extend the term by one year . The facility is available for letters of credit and loans to cash collateralize letter of credit obligations to the extent letters of credit are unavailable under the facility. The facility’s representations and warranties, covenants, and events of default are substantially similar to those in Apache’s $3.5 billion revolving credit facility. Commissions are payable on outstanding letters of credit and borrowings bear interest (at a base rate or LIBOR), plus a margin. Letter of credit commissions, the interest margin, and the facility fee vary depending on Apache’s senior unsecured long-term debt rating. The Company has not requested any letters of credit or borrowings under this facility as of the date of the Previously Filed Annual Report. This facility is available for the Company’s letter of credit needs, particularly those which may arise in respect of abandonment obligations assumed in various North Sea acquisitions. Commercial Paper Program The Company has available a $3.5 billion commercial paper program which generally enables Apache to borrow funds for up to 270 days at competitive interest rates. The commercial paper program is fully supported by available borrowing capacity under the Company’s 2015 committed credit facility. At December 31, 2015, the Company had no commercial paper outstanding. As of December 31, 2014, the Company had $1.6 billion in commercial paper outstanding. Subsidiary Notes – Apache Finance Canada Apache Finance Canada has approximately $300 million of publicly traded notes due in 2029 that are fully and unconditionally guaranteed by Apache. For further discussion of subsidiary debt, please see Note 18—Supplemental Guarantor Information. Financing Costs, Net The following table presents the components of Apache’s financing costs, net: For the Year Ended December 31, 2015 2014 2013 (In millions) Interest expense $ 486 $ 499 $ 560 Amortization of deferred loan costs 11 6 8 Capitalized interest (15 ) (85 ) (99 ) Loss (gain) on extinguishment of debt 39 — (16 ) Interest income (10 ) (7 ) (8 ) Financing costs, net $ 511 $ 413 $ 445 As of December 31, 2015, the Company has $53 million of debt discounts, which will be charged to interest expense over the life of the related debt issuances. Discount amortization of $3 million was recorded as interest expense in each of 2015, 2014, and 2013.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES Income (loss) from continuing operations before income taxes is composed of the following: For the Year Ended December 31, 2015 2014 2013 (In millions) U.S. $ (9,386 ) $ (4,807 ) $ (1,166 ) Foreign (2,783 ) (2,023 ) 2,113 Total $ (12,169 ) $ (6,830 ) $ 947 The total provision for income taxes from continuing operations consists of the following: For the Year Ended December 31, 2015 2014 2013 (In millions) Current taxes: Federal $ 363 $ (10 ) $ (29 ) State 41 1 — Foreign 31 1,290 1,702 435 1,281 1,673 Deferred taxes: Federal (1,123 ) (671 ) (83 ) State (51 ) (45 ) 17 Foreign (271 ) (1,083 ) (666 ) (1,445 ) (1,799 ) (732 ) Total $ (1,010 ) $ (518 ) $ 941 The total provision for income taxes differs from the amounts computed by applying the U.S. statutory income tax rate to income (loss) before income taxes. A reconciliation of the tax on the Company’s income from continuing operations before income taxes and total tax expense is shown below: For the Year Ended December 31, 2015 2014 2013 (In millions) Income tax expense (benefit) at U.S. statutory rate $ (4,259 ) $ (2,391 ) $ 331 State income tax, less federal benefit (7 ) (28 ) 12 Taxes related to foreign operations (662 ) (147 ) 89 Tax credits (6 ) — 6 Tax on distributed foreign earnings 726 311 225 Foreign tax credit carryforwards (2,090 ) — — Deferred tax on undistributed foreign earnings 1,903 560 — Tax impact of goodwill adjustments 82 161 221 Change in U.K. tax rate (414 ) — — Net change in tax contingencies 20 (3 ) (10 ) Valuation allowances 3,746 1,021 125 All other, net (49 ) (2 ) (58 ) $ (1,010 ) $ (518 ) $ 941 The net deferred income tax liability reflects the net tax impact of timing differences between the assets and liability amounts carried on the books under the U.S. GAAP method of accounting and amounts utilized for income tax purposes. The net deferred income tax liability consists of the following: December 31, 2015 2014 (In millions) Deferred tax assets: Deferred income $ 20 $ — U.S. and state net operating loss carryforwards 329 1,333 Foreign net operating loss carryforwards 1,507 366 Tax credits and other tax incentives 82 42 Foreign tax credit carryforwards 2,090 — Accrued expenses and liabilities 136 68 Asset retirement obligation 1,037 1,202 Property and equipment 1,529 856 Total deferred tax assets 6,730 3,867 Valuation allowance (5,434 ) (1,564 ) Net deferred tax assets 1,296 2,303 Deferred tax liabilities: Other 4 19 Deferred income 140 24 Investment in foreign subsidiaries 1,903 1,119 Property and equipment 1,773 5,755 Total deferred tax liabilities 3,820 6,917 Net deferred income tax liability $ 2,524 $ 4,614 In November 2015, the FASB issued ASU 2015-17 “Balance Sheet Classification of Deferred Taxes,” which requires all companies to classify deferred tax assets, liabilities, and related valuation allowances as noncurrent on the balance sheet effective for annual periods beginning after December 15, 2016, with early adoption allowed. Apache has elected to adopt the accounting standard for the year ended December 31, 2015 and as a result, all deferred tax assets, liabilities, and related valuation allowances are classified as noncurrent on Apache Corporation’s December 31, 2015 consolidated balance sheet. Prior consolidated balance sheets were not retrospectively adjusted. Net deferred tax assets and liabilities are included in the consolidated balance sheet as follows: December 31, 2015 2014 (In millions) Assets: Deferred tax asset $ — $ (890 ) Deferred charges and other (5 ) (17 ) Liabilities Other current liabilities — 28 Deferred income taxes 2,529 5,493 Net deferred income tax liability $ 2,524 $ 4,614 In 2015, Apache repatriated the sales proceeds from the divestment of its interest in LNG projects and Australian upstream assets. Upon the repatriation of these proceeds, Apache recognized a U.S. current income tax liability of $560 million . Pursuant to its plan of divestiture of these assets, Apache recorded a deferred income tax liability of $560 million on undistributed foreign earnings in 2014. In 2014, Apache evaluated its permanent reinvestment position and determined that undistributed earnings from certain foreign subsidiaries located in Apache’s Australia, Egypt, and North Sea regions will no longer be permanently reinvested. As a result of this change in position, the Company recorded $560 million of U.S. deferred income tax expense on undistributed earnings that were previously considered permanently reinvested as a component of continuing operations. In addition, the Company recorded $311 million and $225 million of U.S. deferred income tax expense on foreign earnings that were distributed to the U.S. in 2014 and 2013, respectively. The Company’s Canadian subsidiaries do not currently have undistributed earnings. In 2015, the U.K. government enacted Finance Bill 2015 that provides tax relief to exploration and development (E&P) companies operating in the North Sea through a reduction of Supplementary Charge from 32 percent to 20 percent , effective January 1, 2015. As a result of the enacted legislation, in 2015, Apache recorded a deferred tax benefit of $414 million related to the remeasurement of the Company’s December 31, 2014 U.K. deferred income tax liability. The Company has recorded an increase in valuation allowance against certain foreign deferred tax assets, primarily driven by asset impairments. The Company has assessed the future potential realization of these deferred tax assets and has concluded that it is more likely than not that these foreign deferred tax assets will not be realized based on current economic conditions and expectations for the future. In 2015, 2014, and 2013, the Company increased its total valuation allowance by $3.9 billion , $966 million , and $223 million , respectively, as detailed in the table below: 2015 2014 2013 (In millions) Balance at beginning of year $ 1,564 $ 598 $ 375 State (1) 151 62 30 U.S. 2,159 — — Foreign (2) 1,560 1,021 125 Discontinued operations (3) — (117 ) 68 Balance at end of year $ 5,434 $ 1,564 $ 598 (1) Reported as a component of state income taxes in the rate reconciliation. (2) In 2015, Apache’s subsidiaries completed the sale of its interest in the Kitimat LNG project. As such, the deferred tax assets, liabilities, and valuation allowance related to the project were removed for 2015. (3) In 2014, Apache’s subsidiaries completed the sale of all of the Company’s operations in Argentina. As such, the deferred tax assets, liabilities, and valuation allowance related to Argentina were removed for 2014. On December 31, 2015, the Company had net operating losses as follows: Amount Expiration (In millions) Net operating losses: U.S. $ 198 2018 - 2035 State 3,496 Various Canada 60 2028 - 2035 The Company has a U.S. net operating loss carryforward of $198 million subject to annual limitation under Section 382 of the Internal Revenue Code. The Company also has $848 million of capital loss carryforwards in Canada, which have an indefinite carryover period. The Company has recorded a valuation allowance against the net operating losses listed above and the capital loss until there is sufficient evidence to support the reversal of all or some portion of this allowance. On December 31, 2015, the Company had foreign tax credits as follows: Amount Expiration (In millions) Foreign Tax Credits $ 2,090 2025-2026 The Company has a $2.1 billion U.S. foreign tax credit carryforward. The Company has recorded a valuation allowance against the U.S. foreign tax credits listed above until there is sufficient evidence to support the reversal of all or some portion of this allowance. The Company accounts for income taxes in accordance with ASC Topic 740, “Income Taxes,” which prescribes a minimum recognition threshold a tax position must meet before being recognized in the financial statements. Tax positions generally refer to a position taken in a previously filed income tax return or expected to be included in a tax return to be filed in the future that is reflected in the measurement of current and deferred income tax assets and liabilities. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows: 2015 2014 2013 (In millions) Balance at beginning of year $ — $ 3 $ 3 Additions based on tax positions related to the current year 19 — — Reductions for tax positions of prior years — (3 ) — Balance at end of year $ 19 $ — $ 3 The Company records interest and penalties related to unrecognized tax benefits as a component of income tax expense. Each quarter the Company assesses the amounts provided for and, as a result, may increase (expense) or reduce (benefit) the amount of interest and penalties. During the years ended December 31, 2015, 2014, and 2013 the Company recorded tax expense of $1 million , tax benefit of $1 million , and tax expense of $1 million , respectively, for interest and penalties. At December 31, 2015, 2014, and 2013 the Company had an accrued liability for interest and penalties of $1 million , $0 , and $1 million , respectively. In 2015, the Company recorded a $19 million reserve for uncertain tax positions related to the current year. In 2014, the Internal Revenue Service concluded its audit of the 2011 and 2012 tax years, and the Company reduced its unrecognized tax benefit by $3 million as a result of the conclusion of this audit. In 2013, the Company reached agreement with the IRS regarding an audit of the 2009 and 2010 tax years. There was no change in the Company’s unrecognized tax benefits as a result of this agreement. The resolution of unagreed tax issues in the Company’s open tax years cannot be predicted with absolute certainty, and differences between what has been recorded and the eventual outcomes may occur. The Company believes that it has adequately provided for income taxes and any related interest and penalties for all open tax years. Apache and its subsidiaries are subject to U.S. federal income tax as well as income tax in various states and foreign jurisdictions. The Company’s uncertain tax positions are related to tax years that may be subject to examination by the relevant taxing authority. Apache’s earliest open tax years in its key jurisdictions are as follows: Jurisdiction U.S. 2011 Canada 2011 Egypt 1998 U.K. 2013

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES Legal Matters Apache is party to various legal actions arising in the ordinary course of business, including litigation and governmental and regulatory controls. The Company has an accrued liability of approximately $29 million for all legal contingencies that are deemed to be probable of occurring and can be reasonably estimated. Apache’s estimates are based on information known about the matters and its experience in contesting, litigating, and settling similar matters. Although actual amounts could differ from management’s estimate, none of the actions are believed by management to involve future amounts that would be material to Apache’s financial position, results of operations, or liquidity after consideration of recorded accruals. For material matters that Apache believes an unfavorable outcome is reasonably possible, the Company has disclosed the nature of the matter and a range of potential exposure, unless an estimate cannot be made at this time. It is management’s opinion that the loss for any other litigation matters and claims that are reasonably possible to occur will not have a material adverse effect on the Company’s financial position, results of operations, or liquidity. Argentine Claims On March 12, 2014, the Company and its subsidiaries completed the sale of all of the Company’s subsidiaries’ operations and properties in Argentina to YPF Sociedad Anonima (YPF). As part of that sale, YPF assumed responsibility for all of the past, present, and future litigation in Argentina involving Company subsidiaries, except that Company subsidiaries have agreed to indemnify YPF for certain environmental, tax, and royalty obligations capped at an aggregate of $100 million . The indemnity is subject to specific agreed conditions precedent, thresholds, contingencies, limitations, claim deadlines, loss sharing, and other terms and conditions. On April 11, 2014, YPF provided its first notice of claims pursuant to the indemnity. Company subsidiaries have not paid any amounts under the indemnity but will continue to review and consider claims presented by YPF. Further, Company subsidiaries retain the right to enforce certain Argentina-related indemnification obligations against Pioneer Natural Resources Company (Pioneer) in an amount up to $67.5 million pursuant to the terms and conditions of stock purchase agreements entered in 2006 between Company subsidiaries and subsidiaries of Pioneer. Louisiana Restoration Louisiana surface owners often file lawsuits or assert claims against oil and gas companies, including Apache, claiming that operators and working interest owners in the chain of title are liable for environmental damages on the leased premises, including damages measured by the cost of restoration of the leased premises to their original condition, regardless of the value of the underlying property. From time-to-time restoration lawsuits and claims are resolved by the Company for amounts that are not material to the Company, while new lawsuits and claims are asserted against the Company. With respect to each of the pending lawsuits and claims, the amount claimed is not currently determinable or is not material, except as noted. Further, the overall exposure related to these lawsuits and claims is not currently determinable. While an adverse judgment against Apache is possible, Apache intends to actively defend these lawsuits and claims. On July 24, 2013, a lawsuit captioned Board of Commissioners of the Southeast Louisiana Flood Protection Authority – East v. Tennessee Gas Pipeline Company et al. , Case No. 2013-6911 was filed in the Civil District Court for the Parish of Orleans, State of Louisiana, in which plaintiff on behalf of itself and as the board governing the levee districts of Orleans, Lake Borgne Basin, and East Jefferson alleges that Louisiana coastal lands have been damaged as a result of oil and gas industry activity, including a network of canals for access and pipelines. Plaintiff seeks unspecified damages and injunctive relief in the form of abatement and restoration based on claims of negligence, strict liability, natural servitude of drain, public nuisance, private nuisance, and breach of contract – third party beneficiary. Apache has been indiscriminately named as one of many defendants in the lawsuit. In 2014 the Louisiana state government passed a law (SB 469) clarifying that only entities authorized under the Coastal Zone Management Act may bring litigation to assert claims arising out of the permitted activities. Plaintiff is not one of those authorized entities. On February 13, 2015, the federal court entered judgment in favor of defendants dismissing all of plaintiff’s claims with prejudice on various grounds, and plaintiff has appealed. The overall exposure related to this lawsuit is not currently determinable. While an adverse judgment against Apache might be possible, Apache intends to continue to vigorously oppose the claims, including by defending against plaintiff’s appeal of the federal court’s judgment. On November 8, 2013, Plaquemines Parish filed three lawsuits against Apache and various other oil and gas producers in the Parish’s 25t h Judicial District Court, captioned Parish of Plaquemines v. Rozel Operating Company et al., Docket No. 60-996; Parish of Plaquemines v. Apache Oil Corporation et al., Docket No. 610; and Parish of Plaquemines v. HHE Energy Company et al., Docket No. 60-983. On or about February 4, 2016, Cameron Parish filed six new lawsuits against Apache and various other oil and gas producers in the Parish’s 38t h Judicial District Court, captioned Parish of Cameron v. BEPCO, L.P., et al. , Docket No. 10-19572; Parish of Cameron v. BP America Production Company et al. , Docket No. 10-19576; Parish of Cameron v. Apache Corporation (of Delaware) et al. , Docket No. 10-19579; Parish of Cameron v. Atlantic Richfield Company et al. , Docket No. 10-19577; Parish of Cameron v. Alpine Exploration Companies, Inc., et al. , Docket No. 19580; and Parish of Cameron v. Auster Oil and Gas, Inc., et al , Docket No. 10-19582. Many similar lawsuits have been filed against other oil and gas producers in Parishes across south Louisiana. In these cases, the Parishes, as plaintiffs, allege that certain of defendants’ oil and gas exploration, production, and transportation operations in specified fields were conducted in violation of the State and Local Coastal Resources Management Act of 1978, as amended, and applicable regulations, rules, orders, and ordinances promulgated or adopted thereunder by the Parish or the State of Louisiana. Plaintiffs allege that defendants caused substantial damage to land and water bodies located in the coastal zone of Louisiana. Plaintiffs seek, among other things, unspecified damages for alleged violations of applicable state law within the coastal zone, the payment of costs necessary to clear, re-vegetate, detoxify, and otherwise restore the subject coastal zone as near as practicable to its original condition, and actual restoration of the coastal zone to its original condition. On November 21, 2015, the Plaquemines Parish Council voted to drop all of that Parish’s lawsuits, and as a result Apache anticipates that the Parish’s claims will be dismissed. The Cameron Parish lawsuits are pending. While an adverse judgment against Apache might be possible, Apache intends to vigorously oppose these claims. In a case captioned State of Louisiana and the Cameron Parish School Board v. Apache Corporation et al. , Docket No. 10-18672, in the 38t h Judicial District Court, Parish of Cameron, State of Louisiana, plaintiffs alleged that defendants’ oil and gas exploration and production activities contaminated plaintiffs’ property. Plaintiffs sought damages in the range of $7 million to $96 million , plus exemplary damages, costs, and fees. Apache, a defendant in the case, acquired its interest in the oil and gas operations on plaintiffs’ property from the former operator, defendant Davis Oil Company, and subsequently sold the interest to defendant Wagner Oil Company (Wagner). Apache has settled with plaintiffs on confidential terms, including for an exchange of consideration that is not material to Apache. Apache claims indemnity from, and has reserved all of its rights against, Wagner. Australia Gas Pipeline Force Majeure In June 2008, Company subsidiaries reported a pipeline explosion in Western Australia that interrupted deliveries of natural gas to customers under various long-term contracts. The civil lawsuits concerning the pipeline explosion, all of which were filed in the Supreme Court of Western Australia, have been resolved fully and dismissed on confidential terms, including for an exchange of consideration that is not material to Apache. All matters relating to the Australia gas pipeline force majeure are concluded. Apollo Exploration Lawsuit In a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation , Cause No. CV50538 in the 385t h Judicial District Court, Midland County, Texas, in a Second Amended Petition on February 27, 2015, plaintiffs allege damages in excess of $1.1 billion relating to certain purchase and sale agreements, mineral leases, and areas of mutual interest agreements concerning properties located in Hartley, Moore, Potter, and Oldham Counties, Texas. Apache believes that plaintiffs’ claims lack merit, and further that plaintiffs’ alleged damages are grossly inflated. Apache will vigorously oppose the claims. Escheat Audits In September 2010, the State of Delaware, Department of Finance, Division of Revenue (Unclaimed Property) (Delaware), notified Apache Corporation that Delaware’s consultant, Kelmar Associates (Kelmar), will examine Apache’s books and records and those of its subsidiaries and related entities to determine compliance with Delaware Escheat Laws. After more than five years of review, on January 13, 2016, Delaware confirmed that the Company has no liability for the disbursements property category for transaction years 2004 through 2009, which is a change in the Company’s favor from Delaware’s September 2015 assessment in the amount of $237,000 . Delaware has advised the Company that Kelmar’s review for this property category is not complete for transaction years 1986 through 2003, and is still in process for other property types and years as well. While reserving all rights, the Company will continue to cooperate fully with Delaware until the review is complete. The Company’s exposure for the remainder of the Delaware audit is not currently determinable. At least 30 other states have retained their own consultants and have sent similar audit notifications. The scope of each state’s audit varies. It is possible that one or more of the audits could extend to all 50 states. Burrup-Related Gas Supply Lawsuits In a case captioned Pankaj Oswal v. Apache Corporation , No. WAD 389/2013, in the Federal Court of Australia, District of Western Australia, plaintiff asserted claims against the Company under the Australian Trade Practices Act alleging, among other things, that the Company induced him to make investments covering construction cost overruns on the Burrup Fertilisers ammonia plant in Western Australia (the Burrup plant), which was completed in 2006. Plaintiff sought damages in the amount of $491 million USD. On the eve of a trial that was to commence on February 9, 2015, plaintiff decided to discontinue his lawsuit. On March 18, 2015, the court entered a final order dismissing the case. The lawsuit is concluded in the Company’s favor. The Western Australia lawsuit is one of a number of legal actions involving the Burrup plant. Pankaj Oswal’s shares, and those of his wife Radhika Oswal, together representing 65 percent of Burrup Holdings Limited (BHL, as it was then known, which owns Burrup Fertilisers), were offered for sale by externally-appointed administrators in Australia as a result of events of default on loans made to the Oswals and associated entities by the Australia and New Zealand Banking Group Ltd (ANZ). As part of the sale process, on January 31, 2012, a Company affiliate, Apache Fertilisers Pty Ltd (AFPL), acquired a 49 percent interest in BHL (now known as Yara Pilbara Holdings Pty Ltd, YPHPL), while Yara Australia Pty Ltd (Yara) increased its interest in YPHPL from 35 percent to 51 percent . On October 28, 2015, Yara and its related bodies corporate acquired all of the shares of AFPL. Yara operates the ammonia plant and is proceeding with development of a technical ammonium nitrate (TAN) plant in the Burrup Peninsula region of Western Australia to be developed by a consortium including YPHPL. The old gas sale agreement to supply natural gas to the ammonia plant, and to which a former Company subsidiary was a party, has been modified with, among other things, new pricing, delivery quantities, and term. YPHPL share ownership and the modified gas sale agreement continue to be the subject of ongoing litigation in Australia. In cases captioned Radhika Oswal v. Australia and New Zealand Banking Group Limited & Ors , No. SCI 2011 4653, and Pankaj Oswal v. Australia and New Zealand Banking Group Limited & Ors , No. SCI 2012 1995, in the Supreme Court of Victoria, the Oswal plaintiffs seek to set aside the YPHPL share sales, void the modified gas sale agreement, and recover damages in the range of $833 million to $2.274 billion (plus interest, costs, and fees) allegedly resulting from the sale of their shares at undervalue. The cases are presently set for trial commencing May 2016. The Company is a named defendant and is also defending Apache Energy Limited (now known as Quadrant Energy Australia Limited) and Apache Northwest Pty Ltd (now known as Quadrant Northwest Pty Ltd). Yara has assumed full conduct and control of the defense of AFPL (now known as Chemical Holdings Pty Ltd). Apache believes that plaintiffs’ claims lack merit, and further that plaintiffs’ alleged damages are grossly inflated. Apache will vigorously oppose the claims. Environmental Matters The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, provincial, state, local, and foreign country laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. We maintain insurance coverage, which we believe is customary in the industry, although we are not fully insured against all environmental risks. Apache manages its exposure to environmental liabilities on properties to be acquired by identifying existing problems and assessing the potential liability. The Company also conducts periodic reviews, on a Company-wide basis, to identify changes in its environmental risk profile. These reviews evaluate whether there is a probable liability, the amount, and the likelihood that the liability will be incurred. The amount of any potential liability is determined by considering, among other matters, incremental direct costs of any likely remediation and the proportionate cost of employees who are expected to devote a significant amount of time directly to any possible remediation effort. As it relates to evaluations of purchased properties, depending on the extent of an identified environmental problem, the Company may exclude a property from the acquisition, require the seller to remediate the property to Apache’s satisfaction, or agree to assume liability for the remediation of the property. The Company’s general policy is to limit any reserve additions to any incidents or sites that are considered probable to result in an expected remediation cost exceeding $300,000 . Any environmental costs and liabilities that are not reserved for are treated as an expense when actually incurred. In Apache’s estimation, neither these expenses nor expenses related to training and compliance programs are likely to have a material impact on its financial condition. As of December 31, 2015, the Company had an undiscounted reserve for environmental remediation of approximately $52 million . Apache is not aware of any environmental claims existing as of December 31, 2015 that have not been provided for or would otherwise have a material impact on its financial position or results of operations. There can be no assurance however, that current regulatory requirements will not change or past non-compliance with environmental laws will not be discovered on the Company’s properties. With respect to the leak of produced water discovered on June 1, 2013, from a below ground pipeline in the Zama Operations area in northern Alberta, the Alberta Energy Regulator completed its investigation of the incident and issued an administrative penalty to Apache Canada Ltd. (ACL) in the amount of $16,500 CAD. The June 2013 leak resulted from a pinhole feature in the outer polyethylene liner of the composite flex line. On October 19, 2015, the Crown served ACL with a summons and information containing charges relating to a leak of produced water in the Zama area that occurred on or between October 3 and October 25, 2013. The October 2013 leak occurred following damage to a riser by an independent external force. The seven-count charge could result in the levying of a fine. On January 18, 2016, the Crown served ACL with a summons and information containing charges relating to a separate leak of produced water in the Belloy Field operating area that occurred on or about January 20, 2014. The January 2014 leak occurred following the collapse and failure of an internal polyethylene liner on a water injection pipeline. The five-count charge could result in the levying of a fine. ACL will respond to the charges in due course. While the exposure related to these incidents is not currently determinable, the Company does not expect the economic impact of these incidents to have a material effect on the Company’s financial position, results of operations, or liquidity. LNG Divestiture Dispute In respect of the purchase by Woodside of the Company’s interest in the Wheatstone and Kitimat LNG projects and accompanying upstream oil and gas reserves from the Company and its subsidiaries, the base purchase price is subject to adjustment in accordance with the terms of the applicable sale and purchase agreement. Woodside has notified the Company and its subsidiaries that it seeks purchase price adjustments in the net amounts of $175 million (for working capital adjustments), which the Company and its subsidiaries believe is time-barred, and $214 million (for all other adjustments). To the extent the parties are unable to resolve their differences, the disputes will be referred to an independent accounting expert and/or court proceedings for final determination under the terms of the applicable sale and purchase agreement. The Company believes that under the terms of the sale and purchase agreements, Woodside’s requests for payment of purchase price adjustments lack merit; therefore, the Company has not recorded a liability associated with this dispute. Contractual Obligations At December 31, 2015, contractual obligations for drilling rigs, purchase obligations, firm transportation agreements, and long-term operating leases are as follows: Net Minimum Commitments Total 2016 2017-2018 2019-2020 2021 & Beyond (In millions) Drilling rig commitments $ 405 $ 194 $ 211 $ — $ — Purchase obligations (1) 354 28 115 139 72 Firm transportation agreements 363 96 125 83 59 Office and related equipment 342 43 87 72 140 Other operating lease obligations (2) 64 22 35 6 1 Total Net Minimum Commitments $ 1,528 $ 383 $ 573 $ 300 $ 272 (1) Includes contractual obligations under take-or-pay contracts, NGL processing agreements, and drilling work program commitments. (2) Includes commitments associated with supply and standby vessels, and gas pipeline and land leases. The table above includes leases for buildings, facilities, and related equipment with varying expiration dates through 2035 . Net rental expense, excluding discontinued operations in Argentina and Australia, was $57 million , $45 million , and $40 million for 2015, 2014, and 2013, respectively. Costs incurred under take-or-pay and throughput obligations were $92 million , $89 million , and $72 million for 2015, 2014, and 2013, respectively.

Retirement and Deferred Compens

Retirement and Deferred Compensation Plans	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Retirement and Deferred Compensation Plans	RETIREMENT AND DEFERRED COMPENSATION PLANS Apache Corporation provides retirement benefits to its U.S. employees through the use of multiple plans: a 401(k) savings plan, a money purchase retirement plan, a non-qualified retirement/savings plan, and a non-qualified restorative retirement savings plan. The 401(k) savings plan provides participating employees the ability to elect to contribute up to 50 percent of eligible compensation, as defined, to the plan with the Company making matching contributions up to a maximum of 8 percent of each employee’s annual eligible compensation. In addition, the Company, at its discretion, annually contributes 6 percent of each participating employee’s annual eligible compensation to a money purchase retirement plan. The 401(k) savings plan and the money purchase retirement plan are subject to certain annually-adjusted, government-mandated restrictions that limit the amount of employee and Company contributions. For certain eligible employees, the Company also provides a non-qualified retirement/savings plan or a non-qualified restorative retirement savings plan. These plans allow the deferral of up to 50 percent of each employee’s base salary, up to 75 percent of each employee’s annual bonus (that accepts employee contributions) and the Company’s matching contributions in excess of the government mandated limitations imposed in the 401(k) savings plan and money purchase retirement plan. Vesting in the Company’s contributions in the 401(k) savings plan, the money purchase retirement plan, the non-qualified retirement savings plan and the non-qualified restorative retirement savings plan occurs at the rate of 20 percent for every completed year of employment. Upon a change in control of ownership, immediate and full vesting occurs. Additionally, Apache Canada Ltd. and Apache North Sea Limited maintain separate retirement plans, as required under the laws of Canada and the U.K., respectively. The aggregate annual cost to Apache of all U.S. plans, the money purchase retirement plan, non-qualified retirement/savings plan, and non-qualified restorative retirement savings plan was $77 million , $107 million , and $123 million for 2015, 2014, and 2013, respectively. Apache also provides a funded noncontributory defined benefit pension plan (U.K. Pension Plan) covering certain employees of the Company’s North Sea operations in the U.K. The plan provides defined pension benefits based on years of service and final salary. The plan applies only to employees who were part of BP North Sea’s pension plan as of April 2, 2003, prior to the acquisition of BP North Sea by the Company effective July 1, 2003. Additionally, the Company offers postretirement medical benefits to U.S. employees who meet certain eligibility requirements. Eligible participants receive medical benefits up until the age of 65 or at the date they become eligible for Medicare, provided the participant remits the required portion of the cost of coverage. The plan is contributory with participants’ contributions adjusted annually. The postretirement benefit plan does not cover benefit expenses once a covered participant becomes eligible for Medicare. The following tables set forth the benefit obligation, fair value of plan assets and funded status as of December 31, 2015, 2014, and 2013, and the underlying weighted average actuarial assumptions used for the U.K. Pension Plan and U.S. postretirement benefit plan. Apache uses a measurement date of December 31 for its pension and postretirement benefit plans. 2015 2014 2013 Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits (In millions) Change in Projected Benefit Obligation Projected benefit obligation beginning of year $ 216 $ 22 $ 189 $ 28 $ 177 $ 35 Service cost 5 2 5 3 5 4 Interest cost 8 1 9 1 7 1 Foreign currency exchange rate changes (10 ) — (13 ) — 4 — Actuarial losses (gains) (10 ) — 31 (9 ) — (8 ) Effect of curtailment and settlements — 2 — — — (3 ) Benefits paid (7 ) (2 ) (5 ) (2 ) (4 ) (2 ) Retiree contributions — 1 — 1 — 1 Projected benefit obligation at end of year 202 26 216 22 189 28 Change in Plan Assets Fair value of plan assets at beginning of year 206 — 191 — 170 — Actual return on plan assets 1 — 25 — 15 — Foreign currency exchange rates (10 ) — (13 ) — 4 — Employer contributions 7 1 8 1 6 1 Benefits paid (7 ) (2 ) (5 ) (2 ) (4 ) (2 ) Retiree contributions — 1 — 1 — 1 Fair value of plan assets at end of year 197 — 206 — 191 — Funded status at end of year $ (5 ) $ (26 ) $ (10 ) $ (22 ) $ 2 $ (28 ) Amounts recognized in Consolidated Balance Sheet Current liability $ — $ (2 ) $ — $ (1 ) $ — $ (1 ) Non-current asset (liability) (5 ) (24 ) (10 ) (21 ) 2 (27 ) $ (5 ) $ (26 ) $ (10 ) $ (22 ) $ 2 $ (28 ) Pre-tax Amounts Recognized in Accumulated Other Comprehensive Income (Loss) Accumulated gain (loss) $ (32 ) $ 9 $ (37 ) $ 10 $ (22 ) $ 1 Weighted Average Assumptions used as of December 31 Discount rate 3.90 % 3.95 % 3.70 % 3.62 % 4.60 % 4.33 % Salary increases 4.60 % N/A 4.60 % N/A 4.90 % N/A Expected return on assets 4.10 % N/A 3.90 % N/A 5.60 % N/A Healthcare cost trend Initial N/A 7.00 % N/A 7.00 % N/A 7.00 % Ultimate in 2025 N/A 5.00 % N/A 5.00 % N/A 5.00 % As of December 31, 2015, 2014, and 2013, the accumulated benefit obligation for the U.K. Pension Plan was $169 million , $183 million , and $160 million , respectively. Apache’s defined benefit pension plan assets are held by a non-related trustee who has been instructed to invest the assets in a blend of equity securities and low-risk debt securities. The Company intends that this blend of investments will provide a reasonable rate of return such that the benefits promised to members are provided. The U.K. Pension Plan policy is to target an ongoing funding level of 100 percent through prudent investments and includes policies and strategies such as investment goals, risk management practices, and permitted and prohibited investments. A breakout of previous allocations for plan asset holdings and the target allocation for the Company’s plan assets are summarized below: Target Allocation Percentage of Plan Assets at Year-End 2015 2015 2014 Asset Category Equity securities: U.K. quoted equities 14 % 14 % 14 % Overseas quoted equities 26 % 26 % 26 % Total equity securities 40 % 40 % 40 % Debt securities: U.K. Government bonds 48 % 48 % 48 % U.K. corporate bonds 12 % 12 % 12 % Debt securities 60 % 60 % 60 % Total 100 % 100 % 100 % The plan’s assets do not include any direct ownership of equity or debt securities of Apache. The fair value of plan assets is based upon unadjusted quoted prices for identical instruments in active markets, which is a Level 1 fair value measurement. The following tables present the fair values of plan assets for each major asset category based on the nature and significant concentration of risks in plan assets at December 31, 2015 and December 31, 2014: Fair Value Measurements Using: Quoted Price in Active Markets (Level 1) Significant Other Inputs (Level 2) Unobservable Inputs (Level 3) Total Fair Value (In millions) December 31, 2015 Equity securities: U.K. quoted equities (1) $ 27 $ — $ — $ 27 Overseas quoted equities (2) 53 — — 53 Total equity securities 80 — — 80 Debt securities: U.K. Government bonds (3) 93 — — 93 U.K. corporate bonds (4) 24 — — 24 Total debt securities 117 — — 117 Fair value of plan assets $ 197 $ — $ — $ 197 December 31, 2014 Equity securities: U.K. quoted equities (1) $ 28 $ — $ — $ 28 Overseas quoted equities (2) 54 — — 54 Total equity securities 82 — — 82 Debt securities: U.K. Government bonds (3) 99 — — 99 U.K. corporate bonds (4) 25 — — 25 Total debt securities 124 — — 124 Fair value of plan assets $ 206 $ — $ — $ 206 (1) This category comprises U.K. passive equities, which are benchmarked against the FTSE 350 Index. (2) This category includes overseas equities, which comprises 30.3 percent passive global equities benchmarked against the MSCI World (NDR) Index, 12.1 percent passive global equities (hedged) benchmarked against the MSCI World (NDR) Hedged Index, 30.3 percent fundamental indexation global equities benchmarked against the FTSE RAFI Developed 1000 index, 12.1 percent fundamental indexation global equities (hedged) benchmarked against the FTSE RAFI Developed 1000 Hedge Index, and 15.2 percent emerging markets benchmarked against the MSCI Emerging Markets (NDR) Index, which has a performance target of 2 percent per annum over the benchmark over a rolling three -year period. (3) This category includes U.K. Government bonds, which comprises 48 percent index-linked gilts benchmarked against the FTSE Actuaries Government Securities Index-Linked Over 5 Years Index, 37 percent sterling nominal LDI bonds, and 15 percent sterling inflation linked LDI bonds, both benchmarked against ILIM Custom Benchmark index. (4) This category comprises U.K. corporate bonds: 12 percent benchmarked against the BofAML Sterling Corporate & Collaterlised (excluding Subordinated) Index with a performance target of 0.75 percent per annum over the benchmark over a rolling five -year period. The expected long-term rate of return on assets assumptions are derived relative to the yield on long-dated fixed-interest bonds issued by the U.K. government (gilts). For equities, outperformance relative to gilts is assumed to be 3.5 percent per year. The following tables set forth the components of the net periodic cost and the underlying weighted average actuarial assumptions used for the pension and postretirement benefit plans as of December 31, 2015, 2014, and 2013: 2015 2014 2013 Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits (In millions) Component of Net Periodic Benefit Costs Service cost $ 5 $ 2 $ 5 $ 3 $ 5 $ 4 Interest cost 8 1 9 1 7 1 Expected return on assets (8 ) — (11 ) — (8 ) — Amortization of actuarial (gain) loss 2 — 1 — 2 — Curtailment (gain) loss — — — — — (3 ) Net periodic benefit cost $ 7 $ 3 $ 4 $ 4 $ 6 $ 2 Weighted Average Assumptions used to determine Net Period Benefit Cost for the Years ended December 31 Discount rate 3.70 % 3.62 % 4.60 % 4.33 % 4.30 % 3.43 % Salary increases 4.60 % N/A 4.90 % N/A 4.60 % N/A Expected return on assets 3.90 % N/A 5.60 % N/A 4.70 % N/A Healthcare cost trend Initial N/A 7.00 % N/A 7.00 % N/A 7.25 % Ultimate in 2025 N/A 5.00 % N/A 5.00 % N/A 5.00 % Assumed health care cost trend rates affect amounts reported for postretirement benefits. A one-percentage-point change in assumed health care cost trend rates would have the following effects: Postretirement Benefits 1% Increase 1% Decrease (In millions) Effect on service and interest cost components $ 1 $ (1 ) Effect on postretirement benefit obligation 4 (3 ) Apache expects to contribute approximately $7 million to its pension plan and $2 million to its postretirement benefit plan in 2016. The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid: Pension Benefits Postretirement Benefits (In millions) 2016 $ 4 $ 2 2017 4 2 2018 4 2 2019 4 2 2020 4 2 Years 2021-2025 22 10

Capital Stock

Capital Stock	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Capital Stock	CAPITAL STOCK Common Stock Outstanding 2015 2014 2013 Balance, beginning of year 376,504,892 395,772,908 391,640,770 Shares issued for stock-based compensation plans: Treasury shares issued 17,525 17,454 25,214 Common shares issued 1,511,758 1,665,259 929,596 Common shares issued for conversion of preferred shares — — 14,399,247 Treasury shares acquired — (20,950,729 ) (11,221,919 ) Balance, end of year 378,034,175 376,504,892 395,772,908 Net Income (Loss) per Common Share A reconciliation of the components of basic and diluted net income per common share for the years ended December 31, 2015 , 2014 , and 2013 is presented in the table below. 2015 2014 2013 Loss Shares Per Share Loss Shares Per Share Income (Loss) Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ (10,844 ) 378 $ (28.70 ) $ (6,653 ) 384 $ (17.32 ) $ (94 ) 395 $ (0.24 ) Income (loss) from discontinued operations 492 378 1.30 (1,707 ) 384 (4.44 ) 438 395 1.11 Income (loss) attributable to common stock $ (10,352 ) 378 $ (27.40 ) $ (8,360 ) 384 $ (21.76 ) $ 344 395 $ 0.87 Effect of Dilutive Securities: Mandatory Convertible Preferred Stock $ — — $ — — $ — — Stock options and other — — — — — — Diluted: Income (loss) from continuing operations $ (10,844 ) 378 $ (28.70 ) $ (6,653 ) 384 $ (17.32 ) $ (94 ) 395 $ (0.24 ) Income (loss) from discontinued operations 492 378 1.30 (1,707 ) 384 (4.44 ) 438 395 1.11 Income (loss) attributable to common stock $ (10,352 ) 378 $ (27.40 ) $ (8,360 ) 384 $ (21.76 ) $ 344 395 $ 0.87 The diluted EPS calculation excludes options and restricted shares that were anti-dilutive totaling 7.0 million , 4.5 million , and 6.8 million for the years ended December 31, 2015 , 2014 , and 2013 , respectively. For the year ended December 31, 2013, 8.3 million shares related to the assumed conversion of the Mandatory Convertible Preferred Stock were also anti-dilutive. Stock Repurchase Program Apache’s Board of Directors has authorized the purchase of up to 40 million shares of the Company’s common stock. Shares may be purchased either in the open market or through privately held negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through December 31, 2014, had repurchased a total of 32.2 million shares at an average price of $88.96 per share. The Company has not purchased any additional shares during 2015, and is not obligated to acquire any specific number of shares. Common Stock Dividend The Company paid common stock dividends of $1.00 per share in 2015, $0.95 per share in 2014, and $0.77 per share in 2013. Stock Compensation Plans The Company has several stock-based compensation plans, which include stock options, stock appreciation rights, restricted stock, and conditional restricted stock unit plans. On May 5, 2011, the Company’s shareholders approved the 2011 Omnibus Equity Compensation Plan (the 2011 Plan), which is intended to provide eligible employees with equity-based incentives. The 2011 Plan provides for the granting of Incentive Stock Options, Non-Qualified Stock Options, Performance Awards, Restricted Stock, Restricted Stock Units, Stock Appreciation Rights, or any combination of the foregoing. A total of 18.0 million shares were authorized and available for grant under the 2011 Plan as of December 31, 2015. Previously approved plans remain in effect solely for the purpose of governing grants still outstanding that were issued prior to approval of the 2011 Plan. All new grants are issued from the 2011 Plan. For 2015, 2014, and 2013, stock-based compensation expensed was $100 million , $148 million , and $136 million ( $65 million , $95 million , and $94 million after tax), respectively. Costs related to the plans are capitalized or expensed based on the nature of each employee’s activities. A description of the Company’s stock-based compensation plans and related costs follows: 2015 2014 2013 (In millions) Stock-based compensation expensed: General and administrative $ 64 $ 107 $ 89 Lease operating expenses 36 41 47 Stock-based compensation for exploration and development activities 53 62 55 $ 153 $ 210 $ 191 Stock Options As of December 31, 2015, the Company had issued options to purchase shares of the Company’s common stock under one or more of the employee stock option plans adopted in 2000 and 2005 (collectively, the Stock Option Plans), as well as the 2007 Omnibus Equity Compensation Plan (the 2007 Plan), and the 2011 Plan discussed above (together, the Omnibus Plans). New shares of Company stock will be issued for employee stock option exercises; however, under the 2000 Stock Option Plan, shares of treasury stock are used for employee stock option exercises to the extent treasury stock is held. Under the Stock Option Plans and the Omnibus Plans, the exercise price of each option equals the closing price of Apache’s common stock on the date of grant. Prior to 2016, options generally become exercisable ratably over a four-year period and expire 10 years after granted. The Omnibus Plans and all of the Stock Option Plans, except for the 2000 Stock Option Plan, were submitted to and approved by the Company’s shareholders. A summary of stock options issued and outstanding under the Stock Option Plans and the Omnibus Plans is presented in the table and narrative below: 2015 Shares Under Option Weighted Average Exercise Price (In thousands) Outstanding, beginning of year 6,445 $ 90.34 Granted — — Exercised (280 ) 56.72 Forfeited or expired (1,234 ) 93.28 Outstanding, end of year (1) 4,931 91.52 Expected to vest (1) 566 81.77 Exercisable, end of year (1) 4,311 92.92 (1) As of December 31, 2015, the weighted average remaining contractual life for options outstanding, expected to vest, and exercisable is 4.5 years, 6.9 years, and 4.1 years, respectively. The aggregate intrinsic value of options outstanding, expected to vest, and exercisable at year-end was nil. The intrinsic value of options exercised during 2015, 2014, and 2013 was approximately $3 million , $13 million and $4 million , respectively. The cash received from exercise of options during 2015 was approximately $16 million . The Company realized an additional tax benefit of approximately $973,767 for the amount of intrinsic value in excess of compensation cost recognized in 2015. As of December 31, 2015, the total compensation cost related to non-vested options not yet recognized was $5 million , which will be recognized over the remaining vesting period of the options. In February 2016, the Company issued 872,574 options to purchase shares of the Company’s common stock to eligible employees under the 2011 Plan. The total compensation cost of $9 million is estimated to be recognized over a three years vesting period of these options. Restricted Stock and Restricted Stock Units The Company has restricted stock and restricted stock unit plans for eligible employees including officers. The programs created under the Omnibus Plans have been approved by Apache’s Board of Directors. In 2015, the Company awarded 2,976,562 restricted stock units at a weighted-average per-share market price of $61.65 . In 2014 and 2013, the Company awarded 3,046,744 and 3,098,029 restricted stock units at a weighted-average per-share market price of $86.87 and $82.95 , respectively. The value of the stock issued was established by the market price on the date of grant and is being recorded as compensation expense ratably over the vesting terms. During 2015, 2014, and 2013, $90 million ( $58 million after tax), $93 million ( $60 million after tax), and $82 million ( $53 million after tax), respectively, was charged to expense. In 2015, 2014, and 2013, $48 million , $43 million , and $30 million was for exploration and development activities, respectively. As of December 31, 2015, there was $217 million of total unrecognized compensation cost related to 4,570,203 unvested restricted stock units. The weighted-average remaining life of unvested restricted stock units is approximately 1.1 years. The fair value of the awards vested during 2015, 2014 and 2013 was approximately $149 million , $138 million , and $88 million , respectively. A summary of restricted stock activity for the year ended December 31, 2015, is presented below. Shares Weighted- Average Grant- Date Fair Value (In thousands) Non-vested at January 1, 2015 4,784 $ 81.96 Granted 2,976 61.65 Vested (1,839 ) 81.14 Forfeited (1,351 ) 78.26 Non-vested at December 31, 2015 4,570 70.12 In February 2016, the Company issued 2,881,924 shares of restricted stock units at a weighted-average per-share market price of $41.24 under the 2011 Plan to eligible employees. The total compensation cost of $119 million is estimated to be recognized over a three year vesting period of these restricted stock units. Total Shareholder Return (TSR) Stock Units To provide long-term incentives for Apache employees to deliver competitive returns to the Company’s stockholders, the Company has granted conditional restricted stock units to eligible employees. The ultimate number of shares awarded from these conditional restricted stock units is based upon measurement of total shareholder return of Apache common stock as compared to a designated peer group during a three-year performance period. Should any restricted stock units be awarded at the end of the three-year performance period, 50 percent of restricted stock units awarded will immediately vest, and an additional 25 percent will vest on succeeding anniversaries of the end of the performance period. Grants from the total shareholder return programs were outstanding at December 31, 2015, as described below: • In January 2013, the Company’s Board of Directors approved the 2013 TSR Program, pursuant to the 2011 Plan. In January 2013 eligible employees received initial conditional restricted stock unit awards totaling 1,232,176 units. In May 2013, the Company’s Board of Directors cancelled 918,016 awards under the 2013 Performance Program for nonexecutive employees. A total of 108,217 awards were outstanding at December 31, 2015, from which a minimum of zero and a maximum of 216,434 units could be awarded. • In January 2014, the Company’s Board of Directors approved the 2014 TSR Program, pursuant to the 2011 Plan. In January 2014 eligible employees received initial conditional restricted stock unit awards totaling 157,406 units. A total of 63,995 awards were outstanding at December 31, 2015, from which a minimum of zero and a maximum of 127,990 units could be awarded. The fair value cost of the awards was estimated on the date of grant and is being recorded as compensation expense ratably over the vesting terms. During 2015, 2014, and 2013, $648,000 ( $418,000 after tax), $18 million ( $11 million after tax), and $27 million ( $17 million after tax), respectively, was charged to expense. During 2015, 2014, and 2013, $267,000 , $7 million , and $13 million was for exploration and development activities, respectively. As of December 31, 2015, there was $4.7 million of total unrecognized compensation cost related to 172,212 unvested conditional restricted stock units. The weighted-average remaining life of the unvested conditional restricted stock units is approximately 1.8 years. Shares Weighted- Average Grant- Date Fair Value (1) (In thousands) Non-vested at January 1, 2015 354 $ 78.13 Granted — — Vested — — Forfeited or expired (182 ) 72.09 Non-vested at December 31, 2015 172 78.22 (1) The fair value of each conditional restricted stock unit award is estimated as of the date of grant using a Monte Carlo simulation with the following assumptions used for all grants made under the plan: (i) a three-year continuous risk-free interest rate; (ii) a constant volatility assumption based on the historical realized stock price volatility of the Company and the designated peer group; and (iii) the historical stock prices and expected dividends of the common stock of the Company and its designated peer group. Business Performance Restricted Stock Units Beginning in 2015, Apache issued a new business performance program to certain eligible employees with 50 percent of the shares payout based upon the TSR program payout model as described above, and the remaining 50 percent of the shares based on performance and financial objectives as defined in the plan. The overall results of the objectives will be calculated at the end of the award’s stated performance period and, if a payout is warranted, applied to the target number of restricted stock units awarded. The actual amount of shares awarded will be between zero and 150 percent of target. The business performance shares will immediately vest 50 percent at the end of the three -year performance period, with the remaining 50 percent vesting at the end of the following year. In February 2015, the Company’s Board of Directors approved the 2015 Business Performance Program, pursuant to the 2011 Plan. Eligible employees received initial conditional restricted stock unit awards totaling 602,304 units. A total of 500,972 units were outstanding as of December 31, 2015, from which a minimum of zero and a maximum of 751,458 shares could be awarded. The fair value cost of the awards was estimated on the date of grant and is being recorded as compensation expense ratably over the vesting terms. During 2015, $3.4 million ( $2.2 million after tax) and $1.4 million were charged to expense and for exploration and development activities, respectively. As of December 31, 2015, there was $29 million of total unrecognized compensation cost related to 500,972 unvested conditional restricted stock units. The weighted-average remaining life of the unvested conditional restricted stock units is approximately 2.4 years. Shares Weighted Average Grant- Date Fair Value (1) (In thousands) Non-vested at January 1, 2015 — $ — Granted 602 66.63 Vested — — Forfeited or expired (101 ) 66.63 Non-vested at December 31, 2015 501 66.63 (1) The fair value of each conditional restricted stock unit award is estimated as of the date of grant using a Monte Carlo simulation with the following assumptions used for all grants made under the plan: (i) a three-year continuous risk-free interest rate; (ii) a constant volatility assumption based on the historical realized stock price volatility of the Company and the designated peer group; and (iii) the historical stock prices and expected dividends of the common stock of the Company and its designated peer group. In January 2016, the Company’s Board of Directors approved the 2016 Performance Program, pursuant to the 2011 Plan, with terms similar to the 2015 Performance Program described above. Eligible employees received the initial conditional restricted stock unit totaling 855,263 , with the ultimate number of restricted stock units to be awarded ranging from zero to a maximum of 1,710,526 units. The grant date fair value per award was $36.55 .

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Accumulated Other Comprehensive Loss	ACCUMULATED OTHER COMPREHENSIVE LOSS Components of accumulated other comprehensive loss include the following: For the Year Ended December 31, 2015 2014 2013 (In millions) Currency translation adjustment (1) $ (109 ) $ (109 ) $ (109 ) Unrealized gain (loss) on derivatives (Note 5) — — 1 Unfunded pension and postretirement benefit plan (Note 11) (10 ) (7 ) (7 ) Accumulated other comprehensive loss $ (119 ) $ (116 ) $ (115 ) (1) Currency translation adjustments resulting from translating the Canadian subsidiaries’ financial statements into U.S. dollar equivalents, prior to adoption of the U.S. dollar as their functional currency, were reported separately and accumulated in other comprehensive income (loss).

Major Customers

Major Customers	12 Months Ended
	Dec. 31, 2015
Text Block [Abstract]
Major Customers	MAJOR CUSTOMERS In 2015, 2014, and 2013, purchases by Royal Dutch Shell plc and its subsidiaries accounted for 11 percent , 19 percent , and 24 percent , respectively, of the Company’s worldwide oil and gas production revenues.

Business Segment Information

Business Segment Information	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Business Segment Information	BUSINESS SEGMENT INFORMATION Apache is engaged in a single line of business. Both domestically and internationally, the Company explores for, develops, and produces natural gas, crude oil and natural gas liquids. At December 31, 2015, the Company had production in four reporting segments: the United States, Canada, Egypt, and the U.K. North Sea. Apache also pursues exploration interests in other areas that may over time result in reportable discoveries and development opportunities. Financial information for each area is presented below: United States Canada Egypt (1) North Sea Other International Total (1) (In millions) 2015 Oil and gas production revenues $ 2,637 $ 498 $ 2,095 $ 1,280 $ — $ 6,510 Operating Expenses: Depreciation, depletion, and amortization 1,558 301 927 514 — 3,300 Exploration 2,145 231 154 237 4 2,771 Asset retirement obligation accretion 28 43 — 74 — 145 Lease operating expenses 739 244 522 349 — 1,854 Gathering and transportation 68 89 45 9 — 211 Taxes other than income 184 26 9 63 — 282 Impairments 6,266 1,593 1,255 211 147 9,472 Operating Income (Loss) $ (8,351 ) $ (2,029 ) $ (817 ) $ (177 ) $ (151 ) (11,525 ) Other Income (Expense): Gain (loss) on divestitures, net 281 Other 98 General and administrative (380 ) Transaction, reorganization, and separation (132 ) Financing costs, net (511 ) Net Loss From Continuing Operations Before Income Taxes $ (12,169 ) Net Property and Equipment $ 11,753 $ 2,074 $ 3,712 $ 3,263 $ 36 $ 20,838 Total Assets $ 12,782 $ 2,225 $ 6,165 $ 4,280 $ 48 $ 25,500 Additions to Net Property and Equipment $ 2,099 $ 403 $ 862 $ 715 $ 27 $ 4,106 United States Canada Egypt (1) North Sea Other International Total (1) (In millions) 2014 Oil and gas production revenues (2) $ 5,744 $ 1,092 $ 3,643 $ 2,316 $ — $ 12,795 Operating Expenses: Depreciation, depletion, and amortization 2,408 439 872 807 — 4,526 Exploration 2,113 162 112 119 (7 ) 2,499 Asset retirement obligation accretion 43 39 — 72 — 154 Lease operating expenses 921 384 499 434 — 2,238 Gathering and transportation 93 123 40 17 — 273 Taxes other than income 350 31 11 185 — 577 Impairments 2,622 2,412 173 1,895 — 7,102 Operating Income (Loss) (2) $ (2,806 ) $ (2,498 ) $ 1,936 $ (1,213 ) $ 7 (4,574 ) Other Income (Expense): Gain (loss) on divestitures, net (1,608 ) Other 285 General and administrative (453 ) Transaction, reorganization, and separation (67 ) Financing costs, net (413 ) Net Income From Continuing Operations Before Income Taxes (2) $ (6,830 ) Net Property and Equipment (2) $ 19,507 $ 4,197 $ 5,141 $ 3,300 $ 9 $ 32,154 Total Assets (2) $ 21,487 $ 4,728 $ 6,926 $ 4,480 $ 544 $ 38,165 Additions to Net Property and Equipment (2) $ 7,006 $ 1,358 $ 1,293 $ 1,060 $ 8 $ 10,725 2013 Oil and gas production revenues (2) $ 6,902 $ 1,224 $ 3,971 $ 2,728 $ — $ 14,825 Operating Expenses: Depreciation, depletion, and amortization 2,690 510 880 976 1 5,057 Exploration 629 86 86 58 83 942 Asset retirement obligation accretion 94 49 — 68 — 211 Lease operating expenses 1,320 459 471 400 — 2,650 Gathering and transportation 84 155 42 7 — 288 Taxes other than income 335 45 8 384 — 772 Impairments 96 274 12 1,061 — 1,443 Operating Income (Loss) (2) $ 1,654 $ (354 ) $ 2,472 $ (226 ) $ (84 ) 3,462 Other Income (Expense): Gain (loss) on divestitures, net (1,231 ) Other (315 ) General and administrative (491 ) Transaction, reorganization, and separation (33 ) Financing costs, net (445 ) Net Income From Continuing Operations Before Income Taxes (2) $ 947 Net Property and Equipment (2) $ 23,440 $ 6,300 $ 4,908 $ 5,064 $ 1 $ 39,713 Total Assets (2) $ 25,488 $ 7,191 $ 7,761 $ 6,334 $ 487 $ 47,261 Additions to Net Property and Equipment (2) $ 6,159 $ 1,065 $ 1,226 $ 1,078 $ 1 $ 9,529 (1) Includes a noncontrolling interest in Egypt. (2) Prior year amounts have been recast to exclude discontinued operations.

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Supplemental Oil and Gas Disclosures (Unaudited)	SUPPLEMENTAL OIL AND GAS DISCLOSURES (Unaudited) Oil and Gas Operations The following table sets forth revenue and direct cost information relating to the Company’s oil and gas exploration and production activities. Apache has no long-term agreements to purchase oil or gas production from foreign governments or authorities. In the second quarter of 2015, Apache completed the sale of its Australian LNG business and oil and gas assets, and as such the results of Australia oil and gas assets have been classified as discontinued operations. United States Canada Egypt (3) North Sea Other International Total (3)(4) (In millions, except per boe) 2015 Oil and gas production revenues $ 2,637 $ 498 $ 2,095 $ 1,280 $ — $ 6,510 Operating cost: Depreciation, depletion, and amortization (1) 1,455 251 780 490 — 2,976 Asset retirement obligation accretion 28 43 — 74 — 145 Lease operating expenses 739 244 522 349 — 1,854 Gathering and transportation 68 89 45 9 — 211 Exploration expenses 2,145 231 154 237 4 2,771 Impairments related to oil and gas properties 6,154 1,031 193 11 — 7,389 Production taxes (2) 178 23 — 58 — 259 Income tax (2,886 ) (369 ) 180 26 — (3,049 ) 7,881 1,543 1,874 1,254 4 12,556 Results of operation $ (5,244 ) $ (1,045 ) $ 221 $ 26 $ (4 ) $ (6,046 ) 2014 Oil and gas production revenues $ 5,744 $ 1,092 $ 3,643 $ 2,316 $ — $ 12,795 Operating cost: Depreciation, depletion, and amortization (1) 2,294 382 735 784 — 4,195 Asset retirement obligation accretion 43 39 — 72 — 154 Lease operating expenses 921 384 499 434 — 2,238 Gathering and transportation 93 123 40 17 — 273 Exploration expenses 2,113 162 112 119 (7 ) 2,499 Impairments related to oil and gas properties 2,372 1,645 173 1,878 — 6,068 Production taxes (2) 342 27 — 177 — 546 Income tax (864 ) (421 ) 938 (723 ) — (1,070 ) 7,314 2,341 2,497 2,758 (7 ) 14,903 Results of operation $ (1,570 ) $ (1,249 ) $ 1,146 $ (442 ) $ 7 $ (2,108 ) 2013 Oil and gas production revenues $ 6,902 $ 1,224 $ 3,971 $ 2,728 $ — $ 14,825 Operating cost: Depreciation, depletion, and amortization (1) 2,579 417 756 953 — 4,705 Asset retirement obligation accretion 94 49 — 68 — 211 Lease operating expenses 1,320 459 471 400 — 2,650 Gathering and transportation 84 155 42 7 — 288 Exploration expenses 629 86 86 58 83 942 Impairments related to oil and gas properties 96 274 12 1,061 — 1,443 Production taxes (2) 324 40 — 382 — 746 Income tax 630 (63 ) 1,198 (125 ) — 1,640 5,756 1,417 2,565 2,804 83 12,625 Results of operation $ 1,146 $ (193 ) $ 1,406 $ (76 ) $ (83 ) $ 2,200 (1) This amount only reflects DD&A of capitalized costs of oil and gas properties and, therefore, does not agree with DD&A reflected on Note 15—Business Segment Information. (2) Only reflects amounts directly related to oil and gas producing properties and, therefore, does not agree with taxes other than income reflected on Note 15—Business Segment Information. (3) Includes noncontrolling interest in Egypt. (4) Prior year amounts have been recast to exclude discontinued operations. Costs Incurred in Oil and Gas Property Acquisitions, Exploration, and Development Activities United States Canada Egypt (2) Australia North Sea Argentina Other International Total (2) (In millions) 2015 Acquisitions: Proved $ 1 $ 8 $ 29 $ — $ — $ — $ — $ 38 Unproved 313 23 — — — — — 336 Exploration 194 51 125 32 246 — 29 677 Development 1,729 151 741 98 479 — — 3,198 Costs incurred (1) $ 2,237 $ 233 $ 895 $ 130 $ 725 $ — $ 29 $ 4,249 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ — $ — $ 8 $ 6 $ 7 $ — $ — $ 21 Asset retirement costs 123 8 — — (66 ) — — 65 2014 Acquisitions: Proved $ 102 $ — $ 11 $ — $ — $ — $ — $ 113 Unproved 1,221 141 — 16 — — — 1,378 Exploration 505 93 207 131 103 9 1 1,049 Development 5,078 789 1,122 990 956 6 — 8,941 Costs incurred (1) $ 6,906 $ 1,023 $ 1,340 $ 1,137 $ 1,059 $ 15 $ 1 $ 11,481 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ 17 $ — $ 9 $ 90 $ 29 $ 3 $ — $ 148 Asset retirement costs 43 175 — 55 34 — — 307 2013 Acquisitions: Proved $ 17 $ — $ 39 $ — $ 125 $ — $ — $ 181 Unproved 195 151 11 — 17 11 — 385 Exploration 617 35 565 168 259 42 22 1,708 Development 5,188 681 599 1,055 661 142 — 8,326 Costs incurred (1) $ 6,017 $ 867 $ 1,214 $ 1,223 $ 1,062 $ 195 $ 22 $ 10,600 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ 50 $ — $ 2 $ 74 $ 32 $ 10 $ — $ 168 Asset retirement costs 480 17 — (30 ) 67 3 — 537 (2) Includes a noncontrolling interest in Egypt. Capitalized Costs The following table sets forth the capitalized costs and associated accumulated depreciation, depletion, and amortization relating to the Company’s oil and gas production, exploration, and development activities: United States Canada Egypt (1) Australia North Sea Other International Total (1) (In millions) 2015 Proved properties $ 18,692 $ 5,812 $ 9,798 $ — $ 7,426 $ — $ 41,728 Unproved properties 1,615 172 25 — 429 36 2,277 20,307 5,984 9,823 — 7,855 36 44,005 Accumulated DD&A (9,027 ) (3,958 ) (6,559 ) — (4,913 ) — (24,457 ) $ 11,280 $ 2,026 $ 3,264 $ — $ 2,942 $ 36 $ 19,548 2014 Proved properties $ 22,791 $ 6,659 $ 9,096 $ 3,919 $ 6,911 $ — $ 49,376 Unproved properties 3,610 675 179 438 579 9 5,490 26,401 7,334 9,275 4,357 7,490 9 54,866 Accumulated DD&A (7,572 ) (3,803 ) (5,779 ) (2,744 ) (4,533 ) — (24,431 ) $ 18,829 $ 3,531 $ 3,496 $ 1,613 $ 2,957 $ 9 $ 30,435 (1) Includes a noncontrolling interest in Egypt. Oil and Gas Reserve Information Proved oil and gas reserves are the estimated quantities of natural gas, crude oil, condensate, and natural gas liquids (NGLs) that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing conditions, operating conditions, and government regulations. Estimated proved developed oil and gas reserves can be expected to be recovered through existing wells with existing equipment and operating methods. The Company reports all estimated proved reserves held under production-sharing arrangements utilizing the “economic interest” method, which excludes the host country’s share of reserves. Estimated reserves that can be produced economically through application of improved recovery techniques are included in the “proved” classification when successful testing by a pilot project or the operation of an active, improved recovery program using reliable technology establishes the reasonable certainty for the engineering analysis on which the project or program is based. Economically producible means a resource which generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation. Reasonable certainty means a high degree of confidence that the quantities will be recovered. Reliable technology is a grouping of one or more technologies (including computational methods) that has been field-tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. In estimating its proved reserves, Apache uses several different traditional methods that can be classified in three general categories: 1) performance-based methods; 2) volumetric-based methods; and 3) analogy with similar properties. Apache will, at times, utilize additional technical analysis such as computer reservoir models, petrophysical techniques, and proprietary 3-D seismic interpretation methods to provide additional support for more complex reservoirs. Information from this additional analysis is combined with traditional methods outlined above to enhance the certainty of our reserve estimates. There are numerous uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production and timing of development expenditures. The reserve data in the following tables only represent estimates and should not be construed as being exact. Crude Oil and Condensate (Thousands of barrels) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 474,837 79,695 106,746 29,053 119,635 15,845 825,811 December 31, 2013 457,981 80,526 119,242 22,524 100,327 14,195 794,795 December 31, 2014 444,440 75,876 128,712 29,996 105,746 — 784,770 December 31, 2015 348,797 67,847 144,164 — 104,255 — 665,063 Proved undeveloped reserves: December 31, 2012 203,068 70,650 17,288 34,808 28,019 2,981 356,814 December 31, 2013 195,835 56,366 16,302 36,703 29,253 2,231 336,690 December 31, 2014 170,125 59,923 14,617 25,775 19,059 — 289,499 December 31, 2015 60,505 38,326 17,856 — 11,309 — 127,996 Total proved reserves: Balance December 31, 2012 677,905 150,345 124,034 63,861 147,654 18,826 1,182,625 Extensions, discoveries and other additions 133,227 10,177 43,738 2,539 1,543 998 192,222 Purchase of minerals in-place 85 — 5 — 3,623 — 3,713 Revisions of previous estimates 1,683 (531 ) 650 (118 ) 18 24 1,726 Production (53,621 ) (6,469 ) (32,883 ) (7,055 ) (23,258 ) (3,422 ) (126,708 ) Sale of properties (105,463 ) (16,630 ) — — — — (122,093 ) Balance December 31, 2013 653,816 136,892 135,544 59,227 129,580 16,426 1,131,485 Extensions, discoveries and other additions 57,011 9,657 38,074 4,254 17,386 5 126,387 Purchase of minerals in-place 15,240 — — — — — 15,240 Revisions of previous estimates 3,083 (812 ) 2,645 (216 ) (7 ) — 4,693 Production (48,789 ) (6,421 ) (32,934 ) (7,494 ) (22,154 ) (620 ) (118,412 ) Sale of properties (65,796 ) (3,517 ) — — — (15,811 ) (85,124 ) Balance December 31, 2014 614,565 135,799 143,329 55,771 124,805 — 1,074,269 Extensions, discoveries and other additions 13,903 4,550 24,524 — 16,579 — 59,556 Purchase of minerals in-place — 1,763 — — — — 1,763 Revisions of previous estimates (173,907 ) (27,966 ) 27,330 11,189 (2,255 ) — (165,609 ) Production (45,138 ) (5,755 ) (33,163 ) (2,778 ) (21,657 ) — (108,491 ) Sale of properties (121 ) (2,218 ) — (64,182 ) (1,908 ) — (68,429 ) Balance December 31, 2015 409,302 106,173 162,020 — 115,564 — 793,059 (1) 2015, 2014, and 2013 includes proved reserves of 54 MMbbls, 48 MMbbls, and 45 MMbbls, respectively, attributable to a noncontrolling interest in Egypt. Natural Gas Liquids (Thousands of barrels) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 154,508 21,996 — — 2,438 5,007 183,949 December 31, 2013 184,485 26,099 — — 2,435 4,110 217,129 December 31, 2014 183,565 17,947 1,346 — 1,770 — 204,628 December 31, 2015 150,265 15,246 1,491 — 1,784 — 168,786 Proved undeveloped reserves: December 31, 2012 60,889 12,258 — — 380 876 74,403 December 31, 2013 63,538 9,970 — — 215 1,009 74,732 December 31, 2014 69,828 7,168 212 — 371 — 77,579 December 31, 2015 24,939 4,839 78 — 295 — 30,151 Total proved reserves: Balance December 31, 2012 215,397 34,254 — — 2,818 5,883 258,352 Extensions, discoveries and other additions 69,231 4,014 — — — — 73,245 Purchase of minerals in-place 45 — — — 295 — 340 Revisions of previous estimates 1,591 546 — — 1 3 2,141 Production (19,922 ) (2,442 ) — — (464 ) (767 ) (23,595 ) Sale of properties (18,319 ) (303 ) — — — — (18,622 ) Balance December 31, 2013 248,023 36,069 — — 2,650 5,119 291,861 Extensions, discoveries and other additions 47,516 1,163 1,820 — 1 — 50,500 Purchase of minerals in-place 2,916 — — — — — 2,916 Revisions of previous estimates 2,594 116 (11 ) — (2 ) — 2,697 Production (21,464 ) (2,256 ) (251 ) — (508 ) (116 ) (24,595 ) Sale of properties (26,192 ) (9,977 ) — — — (5,003 ) (41,172 ) Balance December 31, 2014 253,393 25,115 1,558 — 2,141 — 282,207 Extensions, discoveries and other additions 5,768 1,473 144 — 689 — 8,074 Purchase of minerals in-place — 976 — — — — 976 Revisions of previous estimates (64,226 ) (4,886 ) 255 — (321 ) — (69,178 ) Production (19,684 ) (2,236 ) (388 ) — (413 ) — (22,721 ) Sale of properties (47 ) (357 ) — — (17 ) — (421 ) Balance December 31, 2015 175,204 20,085 1,569 — 2,079 — 198,937 (1) 2015 and 2014 includes proved reserves of 523 Mbbls and 519 Mbbls, respectively, attributable to a noncontrolling interest in Egypt. Natural Gas (Millions of cubic feet) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 2,353,587 1,734,657 690,436 596,052 93,319 365,054 5,833,105 December 31, 2013 2,005,966 1,294,420 621,825 626,543 88,177 289,133 4,926,064 December 31, 2014 1,616,504 990,145 637,187 640,265 87,259 — 3,971,360 December 31, 2015 1,364,174 759,321 776,263 — 85,532 — 2,985,290 Proved undeveloped reserves: December 31, 2012 832,320 403,227 205,055 1,074,018 18,985 97,496 2,631,101 December 31, 2013 667,160 439,037 190,355 975,224 18,988 121,584 2,412,348 December 31, 2014 580,299 527,623 171,696 964,554 23,228 — 2,267,400 December 31, 2015 208,594 162,809 53,969 — 19,760 — 445,132 Total proved reserves: Balance December 31, 2012 3,185,907 2,137,884 895,491 1,670,070 112,304 462,550 8,464,206 Extensions, discoveries and other additions 306,721 359,493 44,382 13,351 2,750 16,515 743,212 Purchase of minerals in-place 855 — — — 10,680 — 11,535 Revisions of previous estimates 61,247 109,551 14,824 (101 ) 32 49 185,602 Production (285,187 ) (181,593 ) (142,517 ) (81,553 ) (18,601 ) (68,397 ) (777,848 ) Sale of properties (596,417 ) (691,878 ) — — — — (1,288,295 ) Balance December 31, 2013 2,673,126 1,733,457 812,180 1,601,767 107,165 410,717 7,338,412 Extensions, discoveries and other additions 203,318 383,077 125,899 81,156 23,803 — 817,253 Purchase of minerals in-place 21,337 — — — — — 21,337 Revisions of previous estimates 35,910 (12,626 ) 17,326 — (54 ) — 40,556 Production (215,829 ) (117,816 ) (146,522 ) (78,104 ) (20,427 ) (12,722 ) (591,420 ) Sale of properties (521,059 ) (468,324 ) — — — (397,995 ) (1,387,378 ) Balance December 31, 2014 2,196,803 1,517,768 808,883 1,604,819 110,487 — 6,238,760 Extensions, discoveries and other additions 40,901 121,216 94,777 — 41,755 — 298,649 Purchase of minerals in-place — 24,727 — — — — 24,727 Revisions of previous estimates (503,939 ) (325,375 ) 61,442 8,162 (22,373 ) — (782,083 ) Production (160,614 ) (100,289 ) (134,870 ) (34,352 ) (23,647 ) — (453,772 ) Sale of properties (383 ) (315,917 ) — (1,578,629 ) (930 ) — (1,895,859 ) Balance December 31, 2015 1,572,768 922,130 830,232 — 105,292 — 3,430,422 (1) 2015, 2014, and 2013 include proved reserves of 277 Bcf, 270 Bcf, and 271 Bcf, respectively, attributable to a noncontrolling interest in Egypt. Total Equivalent Reserves (Thousands barrels of oil equivalent) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 1,021,610 390,800 221,819 128,395 137,626 81,695 1,981,945 December 31, 2013 976,795 322,362 222,880 126,948 117,457 66,494 1,832,936 December 31, 2014 897,422 258,848 236,256 136,707 122,058 — 1,651,291 December 31, 2015 726,424 209,647 275,033 — 120,293 — 1,331,397 Proved undeveloped reserves: December 31, 2012 402,677 150,113 51,464 213,811 31,563 20,106 869,734 December 31, 2013 370,566 139,509 48,028 199,240 32,633 23,504 813,480 December 31, 2014 336,670 155,028 43,446 186,534 23,301 — 744,979 December 31, 2015 120,210 70,300 26,929 — 14,897 — 232,336 Total proved reserves: Balance December 31, 2012 1,424,287 540,913 273,283 342,206 169,189 101,801 2,851,679 Extensions, discoveries and other additions 253,578 74,107 51,135 4,764 2,001 3,751 389,336 Purchase of minerals in-place 273 — 5 — 5,698 — 5,976 Revisions of previous estimates 13,482 18,274 3,121 (135 ) 24 35 34,801 Production (121,074 ) (39,177 ) (56,636 ) (20,647 ) (26,822 ) (15,589 ) (279,945 ) Sale of properties (223,185 ) (132,246 ) — — — — (355,431 ) Balance December 31, 2013 1,347,361 461,871 270,908 326,188 150,090 89,998 2,646,416 Extensions, discoveries and other additions 138,413 74,666 60,877 17,780 21,354 5 313,095 Purchase of minerals in-place 21,712 — — — — — 21,712 Revisions of previous estimates 11,662 (2,800 ) 5,522 (216 ) (18 ) — 14,150 Production (106,225 ) (28,313 ) (57,605 ) (20,511 ) (26,067 ) (2,856 ) (241,577 ) Sale of properties (178,831 ) (91,548 ) — — — (87,147 ) (357,526 ) Balance December 31, 2014 1,234,092 413,876 279,702 323,241 145,359 — 2,396,270 Extensions, discoveries and other additions 26,488 26,226 40,464 — 24,227 — 117,405 Purchase of minerals in-place — 6,860 — — — — 6,860 Revisions of previous estimates (322,123 ) (87,081 ) 37,825 12,549 (6,305 ) — (365,135 ) Production (91,591 ) (24,706 ) (56,029 ) (8,503 ) (26,011 ) — (206,840 ) Sale of properties (232 ) (55,228 ) — (327,287 ) (2,080 ) — (384,827 ) Balance December 31, 2015 846,634 279,947 301,962 — 135,190 — 1,563,733 (1) 2015, 2014, and 2013 include total proved reserves of 101 MMboe, 93 MMboe, and 90 MMboe, respectively, attributable to a noncontrolling interest in Egypt. During 2015, Apache sold a combined 385 MMboe through several divestiture transactions: 55 MMboe in Canada, 328 MMboe in Australia, and 2 MMboe in the North Sea. The Company added 7 MMboe of estimated proved reserves through purchases of minerals in-place and 117 MMboe from extensions, discoveries, and other additions. The Company recorded 53 MMboe in North America, primarily associated with our drilling programs in the Canadian liquid-rich gas targets of Duvernay and Montney formations and Permian Basin drilling for Wolfcamp, Yeso, Lower Spraberry, and Bone Spring formations. The Company also had additional drilling success in the Woodford, Canyon Lime, Marmaton, and Eagle Ford formations in the MidContinent/Gulf Coast region. The international regions contributed 64 MMboe of exploration and development adds with Egypt contributing 40 MMboe from onshore exploration and appraisal activity in the West Kalabsha, Shushan, and Khalda concessions. Egypt also continued development of the Ptah, Berenice, and Razzak fields during 2015. The North Sea offshore region contributed 24 MMboe from exploration success in the Callater discovery and continued development in the Beryl, Forties, and Nevis fields. During 2015, Apache also had combined downward revisions of previously estimated reserves of 365 MMboe. Changes in product prices accounted for 339 MMboe, lease ownership changes accounted for 16 MMboe, and engineering and performance revisions totaled 10 MMboe. Approximately 9 percent of Apache’s year-end 2015 estimated proved developed reserves are classified as proved not producing. These reserves relate to zones that are either behind pipe, or that have been completed but not yet produced, or zones that have been produced in the past, but are not now producing because of mechanical reasons. These reserves are considered to be a lower tier of reserves than producing reserves because they are frequently based on volumetric calculations rather than performance data. Future production associated with behind pipe reserves is scheduled to follow depletion of the currently producing zones in the same wellbores. Additional capital may have to be spent to access these reserves. The capital and economic impact of production timing are reflected in this Note 16, under “Future Net Cash Flows.” Future Net Cash Flows Future cash inflows as of December 31, 2015 and 2014 were calculated using an unweighted arithmetic average of oil and gas prices in effect on the first day of each month in the respective year, except where prices are defined by contractual arrangements. Operating costs, production and ad valorem taxes and future development costs are based on current costs with no escalation. The following table sets forth unaudited information concerning future net cash flows for proved oil and gas reserves, net of income tax expense. Income tax expense has been computed using expected future tax rates and giving effect to tax deductions and credits available, under current laws, and which relate to oil and gas producing activities. This information does not purport to present the fair market value of the Company’s oil and gas assets, but does present a standardized disclosure concerning possible future net cash flows that would result under the assumptions used. United States Canada Egypt (2) Australia North Sea Argentina Total (2) (In millions) 2015 Cash inflows $ 26,610 $ 7,345 $ 11,124 $ — $ 6,994 $ — $ 52,073 Production costs (12,178 ) (3,841 ) (2,185 ) — (3,209 ) — (21,413 ) Development costs (2,255 ) (1,939 ) (1,515 ) — (2,346 ) — (8,055 ) Income tax expense (63 ) — (2,326 ) — (691 ) — (3,080 ) Net cash flows 12,114 1,565 5,098 — 748 — 19,525 10 percent discount rate (6,876 ) (868 ) (1,330 ) — 143 — (8,931 ) Discounted future net cash flows (1) $ 5,238 $ 697 $ 3,768 $ — $ 891 $ — $ 10,594 2014 Cash inflows 73,859 18,966 16,802 19,391 13,916 — 142,934 Production costs (25,875 ) (7,537 ) (2,924 ) (4,105 ) (7,121 ) — (47,562 ) Development costs (4,422 ) (2,453 ) (1,683 ) (1,173 ) (2,776 ) — (12,507 ) Income tax expense (10,657 ) (1,070 ) (4,091 ) (3,202 ) (2,445 ) — (21,465 ) Net cash flows 32,905 7,906 8,104 10,911 1,574 — 61,400 10 percent discount rate (17,639 ) (3,983 ) (2,099 ) (5,875 ) (146 ) — (29,742 ) Discounted future net cash flows (1) $ 15,266 $ 3,923 $ 6,005 $ 5,036 $ 1,428 $ — $ 31,658 (1) Estimated future net cash flows before income tax expense, discounted at 10 percent per annum, totaled approximately $13.1 billion and $43.0 billion as of December 31, 2015 and 2014, respectively. (2) Includes discounted future net cash flows of approximately $1.3 billion and $2.0 billion in 2015 and 2014, respectively, attributable to a noncontrolling interest in Egypt. The following table sets forth the principal sources of change in the discounted future net cash flows: For the Year Ended December 31, 2015 2014 2013 (In millions) Sales, net of production costs $ (4,056 ) $ (10,350 ) $ (12,271 ) Net change in prices and production costs (21,710 ) (1,029 ) 1,438 Discoveries and improved recovery, net of related costs 1,953 6,297 6,892 Change in future development costs 705 (1,136 ) (2,017 ) Previously estimated development costs incurred during the period 1,991 4,462 4,654 Revision of quantities (2,292 ) 256 500 Purchases of minerals in-place 22 508 227 Accretion of discount 3,642 4,442 4,823 Change in income taxes 7,264 836 855 Sales of properties (5,240 ) (4,780 ) (6,232 ) Change in production rates and other (3,343 ) (442 ) (828 ) $ (21,064 ) $ (936 ) $ (1,959 )

Supplemental Quarterly Financia

Supplemental Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Supplemental Quarterly Financial Data (Unaudited)	SUPPLEMENTAL QUARTERLY FINANCIAL DATA (Unaudited) First Second Third Fourth Total (In millions, except per share amounts) 2015 Revenues and other $ 1,653 $ 2,019 $ 1,531 $ 1,405 $ 6,608 Gain (loss) on divestitures (18 ) 227 (5 ) 77 281 Expenses (1) 2,703 3,163 5,645 6,537 18,048 Net income (loss) from continuing operations including noncontrolling interest (1,068 ) (917 ) (4,119 ) (5,055 ) (11,159 ) Net income (loss) from discontinued operations, net of tax (238 ) 120 (17 ) 627 492 Net income (loss) including noncontrolling interest $ (1,306 ) $ (797 ) $ (4,136 ) $ (4,428 ) $ (10,667 ) Net income (loss) attributable to common stock $ (1,334 ) $ (860 ) $ (4,143 ) $ (4,015 ) $ (10,352 ) Basic net income (loss) per common share (2) : Net income (loss) from continuing operations $ (2.91 ) $ (2.60 ) $ (10.91 ) $ (12.28 ) $ (28.70 ) Net income (loss) from discontinued operations (0.63 ) 0.32 (0.04 ) 1.66 1.30 Net income (loss) per share $ (3.54 ) $ (2.28 ) $ (10.95 ) $ (10.62 ) $ (27.40 ) Diluted net income (loss) per common share (2) : Net income (loss) from continuing operations $ (2.91 ) $ (2.60 ) $ (10.91 ) $ (12.28 ) $ (28.70 ) Net income (loss) from discontinued operations (0.63 ) 0.32 (0.04 ) 1.66 1.30 Net income (loss) per share $ (3.54 ) $ (2.28 ) $ (10.95 ) $ (10.62 ) $ (27.40 ) 2014 Revenues and other $ 3,423 $ 3,323 $ 3,476 $ 2,858 $ 13,080 Gain (loss) on divestitures 3 (787 ) — (824 ) (1,608 ) Expenses (1) 2,786 2,839 3,817 8,342 17,784 Net income (loss) from continuing operations including noncontrolling interest 640 (303 ) (341 ) (6,308 ) (6,312 ) Net income (loss) from discontinued operations, net of tax (545 ) 68 (247 ) (983 ) (1,707 ) Net income (loss) including noncontrolling interest $ 95 $ (235 ) $ (588 ) $ (7,291 ) $ (8,019 ) Net income (loss) attributable to common stock $ (18 ) $ (354 ) $ (691 ) $ (7,297 ) $ (8,360 ) Basic net income (loss) per common share (2) : Net income (loss) from continuing operations $ 1.35 $ (1.10 ) $ (1.17 ) $ (16.77 ) $ (17.32 ) Net income (loss) from discontinued operations (1.38 ) 0.18 (0.65 ) (2.61 ) (4.44 ) Net income (loss) per share $ (0.03 ) $ (0.92 ) $ (1.82 ) $ (19.38 ) $ (21.76 ) Diluted net income (loss) per common share (2) : Net income (loss) from continuing operations $ 1.35 $ (1.10 ) $ (1.17 ) $ (16.77 ) $ (17.32 ) Net income (loss) from discontinued operations (1.38 ) 0.18 (0.65 ) (2.61 ) (4.44 ) Net income (loss) per share $ (0.03 ) $ (0.92 ) $ (1.82 ) $ (19.38 ) $ (21.76 ) (1) Continuing operating expenses for 2015 include non-cash asset impairments totaling $2.1 billion , $660 million , $4.1 billion , and $5.1 billion in the first, second, third, and fourth quarters of 2015, respectively. Continuing operating expenses for 2014 include non-cash asset impairments totaling $115 million , $162 million , $123 million , and $8.7 billion in the first, second, third, and fourth quarters of 2014, respectively. (2) The sum of the individual quarterly net income per common share amounts may not agree with full-year net income per common share as each quarterly computation is based on the weighted-average number of common shares outstanding during that period.

Supplemental Guarantor Informat

Supplemental Guarantor Information	12 Months Ended
	Dec. 31, 2015
Guarantees [Abstract]
Supplemental Guarantor Information	SUPPLEMENTAL GUARANTOR INFORMATION In December 1999, Apache Finance Canada issued approximately $300 million of publicly-traded notes due in 2029 , which are fully and unconditionally guaranteed by Apache. The following condensed consolidating financial statements are provided as an alternative to filing separate financial statements. Apache Finance Canada is 100 percent owned by Apache Corporation. As such, these condensed consolidating financial statements should be read in conjunction with Apache’s consolidated financial statements and notes thereto, of which this note is an integral part. Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 1,446 $ — $ 5,064 $ — $ 6,510 Equity in net income (loss) of affiliates (5,254 ) (740 ) 57 5,937 — Other (71 ) 54 96 19 98 Gain (loss) on divestiture 36 — 245 — 281 (3,843 ) (686 ) 5,462 5,956 6,889 OPERATING EXPENSES: Lease operating expenses 399 — 1,455 — 1,854 Gathering and transportation 35 — 176 — 211 Taxes other than income 103 — 179 — 282 Exploration 2,096 — 675 — 2,771 General and administrative 296 — 65 19 380 Depreciation, depletion, and amortization 966 — 2,334 — 3,300 Asset retirement obligation accretion 15 — 130 — 145 Impairments 3,885 — 5,587 — 9,472 Transaction, reorganization, and separation 132 — — — 132 Financing costs, net 475 (14 ) 50 — 511 8,402 (14 ) 10,651 19 19,058 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES (12,245 ) (672 ) (5,189 ) 5,937 (12,169 ) Provision for income taxes (2,065 ) 11 1,044 — (1,010 ) NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (10,180 ) (683 ) (6,233 ) 5,937 (11,159 ) Net loss from discontinued operations, net of tax (172 ) — 664 — 492 NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST (10,352 ) (683 ) (5,569 ) 5,937 (10,667 ) Net income attributable to noncontrolling interest — — (315 ) — (315 ) NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (10,352 ) $ (683 ) $ (5,254 ) $ 5,937 $ (10,352 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (10,355 ) $ (683 ) $ (5,254 ) $ 5,937 $ (10,355 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME For the Year Ended December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 3,399 $ — $ 9,396 $ — $ 12,795 Equity in net income (loss) of affiliates (3,489 ) (1,191 ) 73 4,607 — Other 375 55 (150 ) 5 285 Gain (loss) on divestiture (1,031 ) — (577 ) — (1,608 ) (746 ) (1,136 ) 8,742 4,612 11,472 OPERATING EXPENSES: Lease operating expenses 509 — 1,729 — 2,238 Gathering and transportation 58 — 215 — 273 Taxes other than income 206 — 371 — 577 Exploration 1,966 — 533 — 2,499 General and administrative 370 — 78 5 453 Depreciation, depletion, and amortization 1,493 — 3,033 — 4,526 Asset retirement obligation accretion 31 — 123 — 154 Impairments 1,626 — 5,476 — 7,102 Transaction, reorganization, and separation 67 — — — 67 Financing costs, net 372 (24 ) 65 — 413 6,698 (24 ) 11,623 5 18,302 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES (7,444 ) (1,112 ) (2,881 ) 4,607 (6,830 ) Provision for income taxes 789 6 (1,313 ) — (518 ) NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (8,233 ) (1,118 ) (1,568 ) 4,607 (6,312 ) Net income from discontinued operations, net of tax (127 ) — (1,580 ) — (1,707 ) NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST (8,360 ) (1,118 ) (3,148 ) 4,607 (8,019 ) Net income attributable to noncontrolling interest — — 341 — 341 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (8,360 ) $ (1,118 ) $ (3,489 ) $ 4,607 $ (8,360 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (8,361 ) $ (1,118 ) $ (3,489 ) $ 4,607 $ (8,361 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME For the Year Ended December 31, 2013 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 4,585 $ — $ 10,240 $ — $ 14,825 Equity in net income (loss) of affiliates 722 30 36 (788 ) — Other (399 ) 61 27 (4 ) (315 ) Gain (loss) on divestiture (670 ) — (561 ) — (1,231 ) 4,238 91 9,742 (792 ) 13,279 OPERATING EXPENSES: Lease operating expenses 939 — 1,711 — 2,650 Gathering and transportation 61 — 227 — 288 Taxes other than income 190 — 582 — 772 Exploration 332 — 610 — 942 General and administrative 411 — 84 (4 ) 491 Depreciation, depletion, and amortization 1,668 — 3,389 — 5,057 Asset retirement obligation accretion 67 — 144 — 211 Impairments 60 — 1,383 — 1,443 Transaction, reorganization, and separation 33 — — — 33 Financing costs, net 339 5 101 — 445 4,100 5 8,231 (4 ) 12,332 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES 138 86 1,511 (788 ) 947 Provision (benefit) for income taxes (250 ) 20 1,171 — 941 NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST 388 66 340 (788 ) 6 Net income from discontinued operations, net of tax — — 438 — 438 NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST 388 66 778 (788 ) 444 Preferred stock dividends 44 — — — 44 Net income attributable to noncontrolling interest — — 56 — 56 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 344 $ 66 $ 722 $ (788 ) $ 344 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 360 $ 66 $ 722 $ (788 ) $ 360 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 98 $ 18 $ 2,438 $ — $ 2,554 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 113 — 113 CASH PROVIDED BY OPERATING ACTIVITIES 98 18 2,551 — 2,667 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (1,500 ) — (2,708 ) — (4,208 ) Additions to gas gathering, transmission, and processing facilities (156 ) — (77 ) — (233 ) Proceeds from sale of Kitimat LNG — — 854 — 854 Proceeds from sale of Yara Pilbara — — 391 — 391 Leasehold and property acquisitions (313 ) — (54 ) — (367 ) Proceeds from sale of oil and gas properties, other 163 — 105 — 268 Investment in subsidiaries, net 6,363 — — (6,363 ) — Other (34 ) — 40 — 6 NET CASH USED IN CONTINUING INVESTING ACTIVITIES 4,523 — (1,449 ) (6,363 ) (3,289 ) NET CASH PROVIDED BY DISCONTINUED OPERATIONS — — 4,372 — 4,372 NET CASH USED IN INVESTING ACTIVITIES 4,523 — 2,923 (6,363 ) 1,083 CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net (1,570 ) — — — (1,570 ) Intercompany borrowings (1,621 ) (18 ) (4,724 ) 6,363 — Payments on fixed rate debt (939 ) — — — (939 ) Dividends paid (377 ) — — — (377 ) Distributions to noncontrolling interest — — (129 ) — (129 ) Other (3 ) — 56 — 53 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (4,510 ) (18 ) (4,797 ) 6,363 (2,962 ) NET CASH USED IN FINANCING ACTIVITIES (4,510 ) (18 ) (4,797 ) 6,363 (2,962 ) NET INCREASE IN CASH AND CASH EQUIVALENTS 111 — 677 — 788 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 267 — 412 — 679 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 378 $ — $ 1,089 $ — $ 1,467 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS For the Year Ended December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 3,104 $ 17 $ 3,892 $ — $ 7,013 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 944 — 944 CASH PROVIDED BY OPERATING ACTIVITIES 3,104 17 4,836 — 7,957 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (4,364 ) — (4,244 ) — (8,608 ) Additions to gas gathering, transmission, and processing facilities (9 ) — (872 ) — (881 ) Proceeds from sale of Deepwater Gulf of Mexico assets 1,360 — — — 1,360 Proceeds from sale of Anadarko basin and southern Louisiana assets 1,262 — — — 1,262 Leasehold and property acquisitions (1,475 ) — — — (1,475 ) Proceeds from sale of oil and gas properties 15 — 455 — 470 Investment in subsidiaries, net 1,132 — — (1,132 ) — Other (186 ) — (113 ) — (299 ) NET CASH USED IN CONTINUING INVESTING ACTIVITIES (2,265 ) — (4,774 ) (1,132 ) (8,171 ) NET CASH PROVIDED BY DISCONTINUED OPERATIONS — — (219 ) — (219 ) NET CASH USED IN INVESTING ACTIVITIES (2,265 ) — (4,993 ) (1,132 ) (8,390 ) CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net 1,570 — (2 ) — 1,568 Intercompany borrowings — 8 (1,152 ) 1,144 — Dividends paid (365 ) — — — (365 ) Distributions to noncontrolling interest — — (140 ) — (140 ) Treasury stock activity, net (1,864 ) — — — (1,864 ) Other (68 ) (28 ) 157 (12 ) 49 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (727 ) (20 ) (1,137 ) 1,132 (752 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (42 ) — (42 ) NET CASH USED IN FINANCING ACTIVITIES (727 ) (20 ) (1,179 ) 1,132 (794 ) NET INCREASE (DECREAS) IN CASH AND CASH EQUIVALENTS 112 (3 ) (1,336 ) — (1,227 ) CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 155 3 1,748 — 1,906 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 267 $ — $ 412 $ — $ 679 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS For the Year Ended December 31, 2013 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 1,076 $ 315 $ 6,873 $ — $ 8,264 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 1,164 — 1,164 CASH PROVIDED BY OPERATING ACTIVITIES 1,076 315 8,037 — 9,428 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (3,751 ) — (4,491 ) — (8,242 ) Additions to gas gathering, transmission, and processing facilities (124 ) — (340 ) — (464 ) Proceeds from divestiture of Gulf of Mexico Shelf properties 3,702 — — — 3,702 Leasehold and property acquisitions (195 ) — (234 ) — (429 ) Proceeds from Kitimat LNG transaction, net — 396 — 396 Proceeds from sale of oil and gas properties — — 307 — 307 Other (58 ) — (47 ) — (105 ) NET CASH USED IN CONTINUING INVESTING ACTIVITIES (426 ) — (4,409 ) — (4,835 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (1,874 ) — (1,874 ) NET CASH USED IN INVESTING ACTIVITIES (426 ) — (6,283 ) — (6,709 ) CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net (501 ) — (8 ) — (509 ) Intercompany borrowings 3,056 1 (3,057 ) — — Payments on fixed rate debt (1,722 ) (350 ) — — (2,072 ) Dividends paid (360 ) — — — (360 ) Proceeds from sale of noncontrolling interest — — 2,948 — 2,948 Shares repurchased (997 ) — — — (997 ) Other 29 37 (45 ) — 21 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (495 ) (312 ) (162 ) — (969 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (4 ) — (4 ) NET CASH USED IN FINANCING ACTIVITIES (495 ) (312 ) (166 ) — (973 ) NET INCREASE IN CASH AND CASH EQUIVALENTS 155 3 1,588 — 1,746 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR — — 160 — 160 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 155 $ 3 $ 1,748 $ — $ 1,906 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) ASSETS CURRENT ASSETS: Cash and cash equivalents $ 378 $ — $ 1,089 $ — $ 1,467 Receivables, net of allowance 314 — 939 — 1,253 Inventories 34 — 536 — 570 Drilling advances 16 — 156 — 172 Prepaid assets and other 102 — 188 — 290 Intercompany receivable 5,212 — — (5,212 ) — 6,056 — 2,908 (5,212 ) 3,752 PROPERTY AND EQUIPMENT, NET 6,546 — 14,292 — 20,838 OTHER ASSETS: Intercompany receivable — — 10,744 (10,744 ) — Equity in affiliates 16,092 (807 ) 446 (15,731 ) — Deferred charges and other 96 1,001 813 (1,000 ) 910 $ 28,790 $ 194 $ 29,203 $ (32,687 ) $ 25,500 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable $ 409 $ — $ 209 $ — $ 618 Other current liabilities 539 3 681 — 1,223 Intercompany payable — — 5,212 (5,212 ) — 948 3 6,102 (5,212 ) 1,841 LONG-TERM DEBT 8,418 298 — — 8,716 DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES: Intercompany payable 10,744 — — (10,744 ) — Income taxes (412 ) 4 2,937 — 2,529 Asset retirement obligation 271 — 2,291 — 2,562 Other 933 250 179 (1,000 ) 362 11,536 254 5,407 (11,744 ) 5,453 COMMITMENTS AND CONTINGENCIES APACHE SHAREHOLDERS’ EQUITY 7,888 (361 ) 16,092 (15,731 ) 7,888 Noncontrolling interest — — 1,602 — 1,602 TOTAL EQUITY 7,888 (361 ) 17,694 (15,731 ) 9,490 $ 28,790 $ 194 $ 29,203 $ (32,687 ) $ 25,500 CONDENSED CONSOLIDATING BALANCE SHEET December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) ASSETS CURRENT ASSETS: Cash and cash equivalents $ 267 $ — $ 412 $ — $ 679 Receivables, net of allowance 837 — 1,182 — 2,019 Inventories 24 — 657 — 681 Drilling advances 34 1 248 — 283 Assets held for sale — — 3,381 — 3,381 Deferred tax asset 612 — 278 — 890 Prepaid assets and other 32 — 97 — 129 Intercompany receivable 4,939 — — (4,939 ) — 6,745 1 6,255 (4,939 ) 8,062 PROPERTY AND EQUIPMENT, NET 12,146 — 22,499 — 34,645 OTHER ASSETS: Intercompany receivable 819 — 4,002 (4,821 ) — Equity in affiliates 21,346 (2 ) 324 (21,668 ) — Deferred charges and other 108 1,002 1,447 (1,000 ) 1,557 $ 41,164 $ 1,001 $ 34,527 $ (32,428 ) $ 44,264 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable $ 748 $ 10 $ 352 $ — $ 1,110 Liabilities held for sale — — 428 — 428 Other current liabilities 1,042 1 1,197 — 2,240 Intercompany payable — — 4,939 (4,939 ) — 1,790 11 6,916 (4,939 ) 3,778 LONG-TERM DEBT 10,880 298 — — 11,178 DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES: Intercompany payable 3,882 120 819 (4,821 ) — Income taxes 3,824 — 1,669 — 5,493 Asset retirement obligation 211 — 2,704 — 2,915 Other 2,082 250 (973 ) (1,000 ) 359 9,999 370 4,219 (5,821 ) 8,767 COMMITMENTS AND CONTINGENCIES APACHE SHAREHOLDERS’ EQUITY 18,495 322 21,346 (21,668 ) 18,495 Noncontrolling interest — — 2,046 — 2,046 TOTAL EQUITY 18,495 322 23,392 (21,668 ) 20,541 $ 41,164 $ 1,001 $ 34,527 $ (32,428 ) $ 44,264

Summary of Significant Accoun27

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The accompanying consolidated financial statements include the accounts of Apache and its subsidiaries after elimination of intercompany balances and transactions. The Company’s undivided interests in oil and gas exploration and production ventures and partnerships are proportionately consolidated. The Company consolidates all other investments in which, either through direct or indirect ownership, Apache has more than a 50 percent voting interest or controls the financial and operating decisions. Noncontrolling interests represent third-party ownership in the net assets of a consolidated Apache subsidiary and are reflected separately in the Company’s financial statements. Investments in which Apache holds less than 50 percent of the voting interest are typically accounted for under the equity method of accounting, with the balance recorded as a component of “Deferred charges and other” in Apache’s consolidated balance sheet and results of operations recorded as a component of “Other” under “Revenues and Other” in the Company’s statement of consolidated operations.
Use of Estimates	Use of Estimates Preparation of financial statements in conformity with GAAP and disclosure of contingent assets and liabilities requires management to make estimates and assumptions that affect reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Apache evaluates its estimates and assumptions on a regular basis. Actual results may differ from these estimates and assumptions used in preparation of its financial statements and changes in these estimates are recorded when known. Significant estimates with regard to these financial statements include the fair value determination of acquired assets and liabilities and assets held for sale at year-end (see Note 3—Acquisitions and Divestitures), the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom (see Note 16—Supplemental Oil and Gas Disclosures), the assessment of asset retirement obligations (see Note 7—Asset Retirement Obligation), the estimates of fair value for long-lived assets and goodwill (see “Fair Value Measurements,” “Property and Equipment,” and “Goodwill” sections in this Note 1 below), and the estimate of income taxes (see Note 9—Income Taxes).
Fair Value Measurements	Fair Value Measurements Certain assets and liabilities are reported at fair value on a recurring basis in Apache’s consolidated balance sheet. ASC 820-10-35 provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consist of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments. Level 3 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority. The valuation techniques that may be used to measure fair value include a market approach, an income approach, and a cost approach. A market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. An income approach uses valuation techniques to convert future amounts to a single present amount based on current market expectations, including present value techniques, option-pricing models, and the excess earnings method. The cost approach is based on the amount that currently would be required to replace the service capacity of an asset (replacement cost). Recurring fair value measurements are presented in further detail in Note 8—Debt and Note 11—Retirement and Deferred Compensation Plans. Apache also uses fair value measurements on a nonrecurring basis when certain qualitative assessments of its assets indicate a potential impairment. For the year ended December 31, 2015, the Company recorded asset impairments totaling $11.9 billion in connection with fair value assessments in the current low commodity price environment. Impairments totaling $11.6 billion were recorded for certain property and equipment, which were written down to their fair values. These impairments are discussed in further detail below in “Property and Equipment.” Also in 2015, the Company recorded $163 million for the impairment of goodwill, $148 million for the impairment of an equity method investment sold in the fourth quarter, and $55 million for inventory write-downs. For a discussion of the equity method investment impairment, see Note 3—Acquisitions and Divestitures. For the year ended December 31, 2014, the Company recorded asset impairments totaling $9.1 billion in connection with fair value assessments, including $8.0 billion for property and equipment, $347 million for the impairment of goodwill, $655 million for the impairment of assets held for sale, and $32 million for inventory write-downs. The Company also recorded $833 million in impairments related to the sale of the Company's Australian assets and an additional $271 million in impairment of proved properties and inventory in Australia. These impairments are classified as discontinued operations in 2014. For discussion of these impairments, see “Property and Equipment” and “Goodwill” below and Note 3—Acquisitions and Divestitures.
Cash Equivalents	Cash Equivalents The Company considers all highly liquid short-term investments with a maturity of three months or less at the time of purchase to be cash equivalents. These investments are carried at cost, which approximates fair value. As of December 31, 2015 and 2014, Apache had $1.5 billion and $679 million , respectively, of cash and cash equivalents.
Accounts Receivable and Allowance for Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable are stated at the historical carrying amount net of write-offs and an allowance for doubtful accounts. The carrying amount of Apache’s accounts receivable approximates fair value because of the short-term nature of the instruments. The Company routinely assesses the collectability of all material trade and other receivables. Many of Apache’s receivables are from joint interest owners on properties Apache operates. The Company may have the ability to withhold future revenue disbursements to recover any non-payment of these joint interest billings. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. As of December 31, 2015, 2014, and 2013, the Company had an allowance for doubtful accounts of $103 million , $98 million , and $78 million , respectively. During 2015, Apache’s allowance for doubtful accounts increased $5 million , reflecting additional provisions for the year of $40 million , partially offset by $35 million for uncollectible accounts written off net of recoveries.
Inventories	Inventories Inventories consist principally of tubular goods and equipment, stated at weighted-average cost, and oil produced but not sold, stated at the lower of cost or market.
Property and Equipment	Property and Equipment The carrying value of Apache’s property and equipment represents the cost incurred to acquire the property and equipment, including capitalized interest, net of any impairments. For business combinations, property and equipment cost is based on the fair values at the acquisition date.
Oil and Gas Property	Oil and Gas Property The Company follows the successful efforts method of accounting for its oil and gas property. Under this method of accounting, exploration costs such as exploratory dry holes, exploratory geological and geophysical costs, delay rentals, unproved impairments, and exploration overhead are expensed as incurred. All costs related to production, general corporate overhead, and similar activities are expensed as incurred. If an exploratory well provides evidence to justify potential development of reserves, drilling costs associated with the well are initially capitalized, or suspended, pending a determination as to whether a commercially sufficient quantity of proved reserves can be attributed to the area as a result of drilling. This determination may take longer than one year in certain areas depending on, among other things, the amount of hydrocarbons discovered, the outcome of planned geological and engineering studies, the need for additional appraisal drilling activities to determine whether the discovery is sufficient to support an economic development plan, and government sanctioning of development activities in certain international locations. At the end of each quarter, management reviews the status of all suspended exploratory well costs in light of ongoing exploration activities; in particular, whether the Company is making sufficient progress in its ongoing exploration and appraisal efforts or, in the case of discoveries requiring government sanctioning, whether development negotiations are underway and proceeding as planned. If management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed. Acquisition costs of unproved properties are assessed for impairment at least annually and are transferred to proved oil and gas properties to the extent the costs are associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment based on the Company’s current exploration plans. Unproved oil and gas properties with individually insignificant lease acquisition costs are amortized on a group basis over the average lease term at rates that provide for full amortization of unsuccessful leases upon lease expiration or abandonment. Costs of expired or abandoned leases are charged to exploration expense, while costs of productive leases are transferred to proved oil and gas properties. Costs of maintaining and retaining unproved properties, as well as amortization of individually insignificant leases and impairment of unsuccessful leases, are included in exploration costs in the statement of consolidated operations. Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of crude oil and natural gas, are capitalized. Depreciation of the cost of proved oil and gas properties is calculated using the unit-of-production (UOP) method. The UOP calculation multiplies the percentage of estimated proved reserves produced each quarter by the carrying value of those reserves. The reserve base used to calculate depreciation for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are included in the depreciable cost. Oil and gas properties are grouped for depreciation in accordance with ASC 932 “Extractive Activities - Oil and Gas.” The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field. When circumstances indicate that proved oil and gas properties may be impaired, the Company compares unamortized capitalized costs to the expected undiscounted pre-tax future cash flows for the associated assets grouped at the lowest level for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows, based on Apache’s estimate of future crude oil and natural gas prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 “Fair Value Measurement.” If applicable, the Company utilizes accepted bids as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future production volumes, commodity prices, operating costs, and capital investment plans, considering all available information at the date of review. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Apache has classified these fair value measurements as Level 3 in the fair value hierarchy. The following table represents non-cash impairments of the carrying value of the Company’s proved and unproved property and equipment for 2015, 2014 and 2013: For the Year Ended December 31, 2015 2014 2013 (In millions) Oil and Gas Property: Proved $ 7,389 $ 6,068 $ 1,443 Unproved 2,462 1,976 319 The fair values of the impaired proved properties as of the most recent date of impairment were $3.9 billion , $4.8 billion , and $3.8 billion for 2015, 2014, and 2013, respectively. On the consolidated statement of operations, unproved impairments are recorded in exploration expense, and proved impairments are recorded in impairments. Gains and losses on significant divestitures are recognized in the statement of consolidated operations. See Note 3—Acquisitions and Divestitures for more detail.
Gathering, Transmission, and Processing Facilities	Gathering, Transmission, and Processing Facilities GTP facilities totaled $1.1 billion and $5.4 billion at December 31, 2015 and 2014, respectively, with accumulated depreciation for these assets totaling $160 million and $1.7 billion for the respective periods. GTP facilities are depreciated on a straight-line basis over the estimated useful lives of the assets. The estimation of useful life takes into consideration anticipated production lives from the fields serviced by the GTP assets, whether Apache-operated or third party, as well as potential development plans by Apache for undeveloped acreage within or in close proximity to those fields. The Company assesses the carrying amount of its GTP facilities whenever events or changes in circumstances indicate that their carrying amount may not be recoverable. If the carrying amount of these facilities is more than the sum of the undiscounted cash flows, an impairment loss is recognized for the excess of the carrying value over its fair value. During 2015, the Company recorded impairments of $1.7 billion on certain GTP assets, including $1.1 billion in Egypt, $555 million in Canada, and $103 million in the U.S., which were written down to their fair values of $306 million in aggregate. The fair values of the impaired assets were determined using an income approach, which considered internal estimates of future throughput volumes, processing rates, and costs. These assumptions were applied to develop future cash flow projections that were then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Apache has classified these non-recurring fair value measurements as Level 3 in the fair value hierarchy. During 2014, the Company recorded impairments of $1.1 billion of its GTP assets related to the sale of Apache’s Wheatstone and Kitimat LNG projects, and the remaining carrying value of those assets was reclassified to “Assets held for sale” on the Company’s consolidated balance sheet as of December 31, 2014. The $430 million impairment of GTP assets related to Apache's Wheatstone LNG project is reflected in discontinued operations in the Company's statement of consolidated operations. No impairments of GTP facilities were recognized during 2013. The costs of GTP facilities retired or otherwise disposed of and associated accumulated depreciation are removed from Apache’s consolidated financial statements, and the resulting gain or loss is reflected in “Gain (loss) on divestitures” under “Revenues and Other” in the Company’s statement of consolidated operations. During 2015, Apache recorded a gain on the sale of GTP facilities totaling $59 million associated with the Company’s divestitures of certain Permian Basin assets. During 2014, the Company recorded a loss totaling $180 million associated with divestitures of certain Anadarko basin and southern Louisiana assets. No gain or loss on the sales of GTP facilities was recognized during 2013.
Other Property and Equipment	Other Property and Equipment Other property and equipment includes computer software and equipment, buildings, vehicles, furniture and fixtures, land, and other equipment. These assets are depreciated on a straight-line basis over the estimated useful lives of the assets, which range from 3 to 20 years. Accumulated depreciation for these assets totaled $693 million and $673 million at December 31, 2015 and 2014, respectively.
Asset Retirement Costs and Obligations	Asset Retirement Costs and Obligations The initial estimated asset retirement obligation related to property and equipment is recorded as a liability at its fair value, with an offsetting asset retirement cost recorded as an increase to the associated property and equipment on the consolidated balance sheet. If the fair value of the recorded asset retirement obligation changes, a revision is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from changes in estimated inflation rates, changes in service and equipment costs and changes in the estimated timing of an asset’s retirement. Asset retirement costs are depreciated using a systematic and rational method similar to that used for the associated property and equipment. Accretion expense on the liability is recognized over the estimated productive life of the related assets.
Goodwill	Goodwill Goodwill represents the excess of the purchase price of an entity over the estimated fair value of the assets acquired and liabilities assumed, and it is recorded in "Deferred charges and other" in the Company's consolidated balance sheet. The Company assesses the carrying amount of goodwill by testing for impairment annually and when impairment indicators arise. The impairment test requires allocating goodwill and all other assets and liabilities to assigned reporting units. As of December 31, 2015, Apache assesses each country as a reporting unit. The fair value of each unit is determined and compared to the book value of the reporting unit. If the fair value of the reporting unit is less than the book value, including goodwill, then goodwill is written down to the implied fair value of the goodwill through a charge to expense. In order to determine the fair value of each reporting unit, the Company uses a combination of the income approach and the market approach. The income approach considers management views on current operating measures as well as assumptions pertaining to market forces in the oil and gas industry, such as future production, future commodity prices, and costs. These assumptions are applied to develop future cash flow projections that are then discounted to estimate fair value, using a discount rate similar to those used by the Company in the valuation of acquisitions and divestitures. To assess the reasonableness of its fair value estimate, the Company uses a market approach to compare the fair value to similar businesses whose securities are actively traded in the public market. This requires management to make certain judgments about the selection of comparable companies, recent comparable asset transactions, and transaction premiums. Associated market multiples are applied to various financial metrics of the reporting unit to estimate fair value. Apache has classified this reporting unit estimation as a non-recurring Level 3 fair value measurement. When there is a disposal of a reporting unit or a portion of a reporting unit that constitutes a business, goodwill associated with that business is included in the carrying amount to determine the gain or loss on disposal. The amount of goodwill allocated to the carrying amount of a business can significantly impact the amount of gain or loss recognized on the sale of that business. The amount of goodwill to be included in that carrying amount is based on the relative fair value of the business to be disposed of and the portion of the reporting unit that will be retained. The changes in goodwill in 2014 and 2013 represent amounts allocated to U.S. properties sold in each respective year. The following presents the changes to goodwill for the years ended 2015, 2014, and 2013: United States Canada Egypt North Sea Total (In millions) Goodwill at December 31, 2012 $ 1,016 $ 103 $ 87 $ 83 $ 1,289 Divested (632 ) — — — (632 ) Acquired — — — 80 80 Impairments — — — — — Goodwill at December 31, 2013 384 103 87 163 737 Divested (140 ) — — — (140 ) Impairments (244 ) (103 ) — — (347 ) Goodwill at December 31, 2014 — — 87 163 250 Divested — — — — — Impairments — — — (163 ) (163 ) Goodwill at December 31, 2015 $ — $ — $ 87 $ — $ 87 Reductions in estimated net present value of expected future cash flows from oil and gas properties resulted in implied fair values below the carrying values of Apache’s U.S., North Sea, and Canada reporting units. These goodwill impairments have been recorded in “Impairments” in the Company’s statement of consolidated operations.
Accounts Payable	Accounts Payable Included in accounts payable at December 31, 2015 and 2014, are liabilities of approximately $129 million and $229 million , respectively, representing the amount by which checks issued but not presented to the Company’s banks for collection exceeded balances in applicable bank accounts.
Commitments and Contingencies	Commitments and Contingencies Accruals for loss contingencies arising from claims, assessments, litigation, environmental and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. These accruals are adjusted as additional information becomes available or circumstances change.
Revenue Recognition and Imbalances	Revenue Recognition and Imbalances Oil and gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Cash received relating to future revenues is deferred and recognized when all revenue recognition criteria are met. Apache uses the sales method of accounting for gas production imbalances. The volumes of gas sold may differ from the volumes to which Apache is entitled based on its interests in the properties. These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to Apache will not be sufficient to enable the under-produced owner to recoup its entitled share through production. The Company’s recorded liability is generally reflected in other non-current liabilities. No receivables are recorded for those wells where Apache has taken less than its share of production. Gas imbalances are reflected as adjustments to estimates of proved gas reserves and future cash flows in the unaudited supplemental oil and gas disclosures. Apache markets its own North American natural gas production. Since the Company’s production fluctuates because of operational issues, it is occasionally necessary to purchase third-party oil and gas to fulfill sales obligations and commitments. The costs of third-party oil and gas purchases totaled $105 million , $70 million , and $39 million , for 2015, 2014, and 2013, respectively, which were netted against the related sales proceeds . The Company’s Egyptian operations are conducted pursuant to production sharing contracts under which contractor partners pay all operating and capital costs for exploring and developing the concessions. A percentage of the production, generally up to 40 percent , is available to contractor partners to recover these operating and capital costs over contractually defined periods. Cost recovery is reflected in revenue. The balance of the production is split among the contractor partners and the Egyptian General Petroleum Corporation (EGPC) on a contractually defined basis.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Apache periodically enters into derivative contracts to manage its exposure to commodity price risk. These derivative contracts, which are generally placed with major financial institutions, may take the form of forward contracts, futures contracts, swaps, or options. The oil and gas reference prices upon which the commodity derivative contracts are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company for its oil and gas production. As of December 31, 2015, Apache had no open derivative positions. When applicable, Apache records all derivative instruments, other than those that meet the normal purchases and sales exception, on the balance sheet as either an asset or liability measured at fair value. Changes in fair value are recognized currently in earnings unless specific hedge accounting criteria are met. Gains and losses from the change in fair value of derivative instruments that do not qualify for hedge accounting are reported in current-period income as “Derivative instrument gains (losses), net” under “Revenues and Other” in the statement of consolidated operations. Hedge accounting treatment allows unrealized gains and losses on cash flow hedges to be deferred in other comprehensive income. Realized gains and losses from the Company’s oil and gas cash flow hedges, including terminated contracts, are generally recognized in oil and gas production revenues when the forecasted transaction occurs. If at any time the likelihood of occurrence of a hedged forecasted transaction ceases to be “probable,” hedge accounting treatment will cease on a prospective basis, and all future changes in the fair value of the derivative will be recognized directly in earnings. Amounts recorded in other comprehensive income prior to the change in the likelihood of occurrence of the forecasted transaction will remain in other comprehensive income until such time as the forecasted transaction impacts earnings. If it becomes probable that the original forecasted production will not occur, then the derivative gain or loss would be reclassified from accumulated other comprehensive income into earnings immediately. Hedge effectiveness is measured at least quarterly based on the relative changes in fair value between the derivative contract and the hedged item over time, and any ineffectiveness is immediately reported as “Other” under “Revenues and Other” in the statement of consolidated operations.
Income Taxes	Income Taxes Apache records deferred tax assets and liabilities to account for the expected future tax consequences of events that have been recognized in the financial statements and tax returns. The Company routinely assesses the ability to realize its deferred tax assets. If the Company concludes that it is more likely than not that some or all of the deferred tax assets will not be realized, the tax asset is reduced by a valuation allowance. Numerous judgments and assumptions are inherent in the determination of future taxable income, including factors such as future operating conditions (particularly as related to prevailing oil and gas prices) and changing tax laws. Apache does not record U.S. deferred income taxes on foreign subsidiaries that are deemed to be permanently reinvested. When such earnings are no longer deemed permanently reinvested, Apache will recognize the appropriate U.S. current or deferred income tax liabilities. For more information, please refer to Note 9—Income Taxes.
Foreign Currency Transaction Gains and Losses	Foreign Currency Transaction Gains and Losses The U.S. dollar is the functional currency for each of Apache’s international operations. The functional currency is determined country-by-country based on relevant facts and circumstances of the cash flows, commodity pricing environment and financing arrangements in each country. Foreign currency transaction gains and losses arise when monetary assets and liabilities denominated in foreign currencies are remeasured to their U.S. dollar equivalent at the exchange rate in effect at the end of each reporting period. Foreign currency gains and losses also arise when revenue and disbursement transactions denominated in a country’s local currency are converted to a U.S. dollar equivalent based on the average exchange rates during the reporting period. Foreign currency transaction gains and losses related to current taxes payable and deferred tax assets and liabilities are recorded as components of the provision for income taxes. For further discussion, please refer to Note 9—Income Taxes. All other foreign currency transaction gains and losses are reflected in “Other” under “Revenues and Other” in the statement of consolidated operations. The Company’s other foreign currency gains and losses netted to a loss in 2015 of $11 million , a gain in 2014 of $8 million , and a loss in 2013 of $30 million .
Insurance Coverage	Insurance Coverage The Company recognizes an insurance receivable when collection of the receivable is deemed probable. Any recognition of an insurance receivable is recorded by crediting and offsetting the original charge. Any differential arising between insurance recoveries and insurance receivables is recorded as a capitalized cost or as an expense, consistent with its original treatment.
Earnings Per Share	Earnings Per Share The Company’s basic earnings per share (EPS) amounts have been computed based on the weighted-average number of shares of common stock outstanding for the period. Diluted EPS reflects potential dilution, using the treasury stock method, which assumes that options were exercised and restricted stock was fully vested. The diluted EPS calculations for the year ended December 31, 2013, includes weighted-average shares of common stock from the assumed conversion of Apache’s convertible preferred stock.
Stock-Based Compensation	Stock-Based Compensation The Company accounts for stock-based compensation under the fair value recognition provisions of ASC Topic 718, “Compensation – Stock Compensation.” The Company grants various types of stock-based awards including stock options, nonvested restricted stock units, and performance-based awards. Additionally, the Company also grants cash-based stock appreciation rights. These plans and related accounting policies are defined and described more fully in Note 12—Capital Stock. Stock compensation awards granted are valued on the date of grant and are expensed, net of estimated forfeitures, over the required service period. ASC Topic 718 also requires that benefits of tax deductions in excess of recognized compensation cost be reported as financing cash flows rather than as operating cash flows. The Company classified $1 million , $35,000 , and $1 million as financing cash inflows in 2015, 2014, and 2013, respectively.
Treasury Stock	Treasury Stock The Company follows the weighted-average-cost method of accounting for treasury stock transactions.
New Pronouncements Issued But Not Yet Adopted	New Pronouncements Issued But Not Yet Adopted In September 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2015-16, which eliminates the requirement that an acquirer in a business combination account for measurement-period adjustments retrospectively. Instead, an acquirer will recognize a measurement-period adjustment during the period in which it determines the amount of the adjustment, including amounts it would have recorded in previous periods if the accounting had been completed at the acquisition date. ASU 2015-16 is effective for fiscal years beginning after December 15, 2016. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements. In July 2015, the FASB issued ASU 2015-11, which simplifies the subsequent measurement of inventory by requiring inventory to be measured at the lower of cost and net realizable value. Entities will continue to apply their existing impairment models to inventories that are accounted for using last-in first-out and the retail inventory method. Under current guidance, net realizable value is one of several calculations an entity needs to make to measure inventory at the lower of cost or market. The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements. In May 2014, the FASB and the International Accounting Standards Board (IASB) issued a joint revenue recognition standard, ASU 2014-9. The new standard removes inconsistencies in existing standards, changes the way companies recognize revenue from contracts with customers, and increases disclosure requirements. The guidance requires companies to recognize revenue to depict the transfer of goods or services to customers in amounts that reflect the consideration to which the company expects to be entitled in exchange for those goods or services. In July 2015, the FASB announced a delay in the effective date of the revenue standard by one year. The deferral results in the new revenue standard being effective for annual and interim periods beginning after December 15, 2017. The standard is required to be adopted using either the full retrospective approach, with all prior periods presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet. The Company is currently evaluating the level of effort needed to implement the standard, the impact of adopting this standard on its consolidated financial statements, and whether to use the full retrospective approach or the modified retrospective approach.

Summary of Significant Accoun28

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Schedule of Non-cash Impairments of Proved and Unproved Property and Equipment	The following table represents non-cash impairments of the carrying value of the Company’s proved and unproved property and equipment for 2015, 2014 and 2013: For the Year Ended December 31, 2015 2014 2013 (In millions) Oil and Gas Property: Proved $ 7,389 $ 6,068 $ 1,443 Unproved 2,462 1,976 319
Schedule of Goodwill	The following presents the changes to goodwill for the years ended 2015, 2014, and 2013: United States Canada Egypt North Sea Total (In millions) Goodwill at December 31, 2012 $ 1,016 $ 103 $ 87 $ 83 $ 1,289 Divested (632 ) — — — (632 ) Acquired — — — 80 80 Impairments — — — — — Goodwill at December 31, 2013 384 103 87 163 737 Divested (140 ) — — — (140 ) Impairments (244 ) (103 ) — — (347 ) Goodwill at December 31, 2014 — — 87 163 250 Divested — — — — — Impairments — — — (163 ) (163 ) Goodwill at December 31, 2015 $ — $ — $ 87 $ — $ 87

Change in Accounting Principle

Change in Accounting Principle (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Changes and Error Corrections [Abstract]
Schedule of effects of the change to the successful efforts method	The following tables present the effects of the change to the successful efforts method in the statement of consolidated operations: Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 4,999 $ 108 $ 5,107 Natural gas revenues 1,157 19 1,176 NGL revenues 227 — 227 Oil and gas production revenues 6,383 127 6,510 Other (76 ) 174 98 Gain (loss) on divestiture 59 222 281 Exploration — 2,771 2,771 General and administrative 377 3 380 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 3,531 (555 ) 2,976 Additional 25,517 (25,517 ) — Impairments 1,920 7,552 9,472 Financing costs, net 299 212 511 Current income tax provision 309 126 435 Deferred income tax provision (benefit) (5,778 ) 4,333 (1,445 ) NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (22,757 ) 11,598 (11,159 ) Net loss attributable to noncontrolling interest (409 ) 94 (315 ) NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS (22,348 ) 11,504 (10,844 ) Net income (loss) from discontinued operations, net of tax (771 ) 1,263 492 NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS (23,119 ) 12,767 (10,352 ) Per Common Share Basic net loss from continuing operations per share $ (59.16 ) $ 30.46 $ (28.70 ) Basic net income (loss) from discontinued operations per share (2.04 ) 3.34 1.30 Basic net loss per share $ (61.20 ) $ 33.80 $ (27.40 ) Diluted net loss from continuing operations per share $ (59.16 ) $ 30.46 $ (28.70 ) Diluted net income (loss) from discontinued operations per share (2.04 ) 3.34 1.30 Diluted net loss per share $ (61.20 ) $ 33.80 $ (27.40 ) Other Comprehensive Income Pension and postretirement benefit plan, net of tax $ — $ (3 ) $ (3 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK (23,119 ) 12,764 (10,355 ) Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 10,040 $ 70 $ 10,110 Natural gas revenues 1,983 34 2,017 NGL revenues 668 — 668 Oil and gas production revenues 12,691 104 12,795 Other 290 (5 ) 285 Gain (loss) on divestiture (180 ) (1,428 ) (1,608 ) Exploration — 2,499 2,499 General and administrative 451 2 453 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 4,388 (193 ) 4,195 Additional 5,001 (5,001 ) — Impairments 1,919 5,183 7,102 Financing costs, net 211 202 413 Current income tax provision 1,177 104 1,281 Deferred income tax provision (benefit) (514 ) (1,285 ) (1,799 ) NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (3,472 ) (2,840 ) (6,312 ) Net income attributable to noncontrolling interest 343 (2 ) 341 NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS (3,815 ) (2,838 ) (6,653 ) Net loss from discontinued operations, net of tax (1,588 ) (119 ) (1,707 ) NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS (5,403 ) (2,957 ) (8,360 ) Per Common Share Basic net loss from continuing operations per share $ (9.93 ) $ (7.39 ) $ (17.32 ) Basic net loss from discontinued operations per share (4.13 ) (0.31 ) (4.44 ) Basic net loss per share $ (14.06 ) $ (7.70 ) $ (21.76 ) Diluted net loss from continuing operations per share $ (9.93 ) $ (7.39 ) $ (17.32 ) Diluted net loss from discontinued operations per share (4.13 ) (0.31 ) (4.44 ) Diluted net loss per share $ (14.06 ) $ (7.70 ) $ (21.76 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (5,404 ) $ (2,957 ) $ (8,361 ) Changes to the Statement of Consolidated Operations and Statement of Consolidated Comprehensive Income (Loss) For the Year Ended December 31, 2013 Under Full Cost Changes* As Reported Under Successful Efforts (In millions, except per share data) Oil revenues $ 11,853 $ 17 $ 11,870 Natural gas revenues 2,266 37 2,303 NGL revenues 652 — 652 Oil and gas production revenues 14,771 54 14,825 Other (333 ) 18 (315 ) Gain (loss) on divestiture — (1,231 ) (1,231 ) Exploration — 942 942 General and administrative 481 10 491 Depreciation, depletion, and amortization: Oil and gas property and equipment Recurring 4,534 171 4,705 Additional 995 (995 ) — Other assets 337 15 352 Impairments — 1,443 1,443 Financing costs, net 229 216 445 Current income tax provision 1,619 54 1,673 Deferred income tax provision (benefit) 309 (1,041 ) (732 ) NET INCOME FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST 1,980 (1,974 ) 6 NET INCOME (LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS 1,880 (1,974 ) (94 ) Net income from discontinued operations, net of tax 308 130 438 NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS 2,188 (1,844 ) 344 Per Common Share Basic net income (loss) from continuing operations per share $ 4.75 $ (4.99 ) $ (0.24 ) Basic net income from discontinued operations per share 0.78 0.33 1.11 Basic net loss per share $ 5.53 $ (4.66 ) $ 0.87 Diluted net income (loss) from continuing operations per share $ 4.74 $ (4.98 ) $ (0.24 ) Diluted net income from discontinued operations per share 0.76 0.35 1.11 Diluted net income per share $ 5.50 $ (4.63 ) $ 0.87 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 2,204 $ (1,844 ) $ 360 The following tables present the effects of the change to the successful efforts method in the statement of consolidated cash flows: Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ (23,528 ) $ 12,861 $ (10,667 ) Loss (income) from discontinued operations 771 (1,263 ) (492 ) Loss (gain) on divestitures, net (59 ) (222 ) (281 ) Exploratory dry hole expense and unproved leasehold impairments — 2,595 2,595 Depreciation, depletion, and amortization 29,372 (26,072 ) 3,300 Impairments 1,920 7,552 9,472 Other noncash items, net 161 (154 ) 7 Provision for (benefit from) deferred income taxes (5,778 ) 4,333 (1,445 ) Changes in operating assets and liabilities (170 ) 90 (80 ) Net cash provided by operating activities - continuing operations 2,834 (280 ) 2,554 Net cash provided by operating activities - discontinued operations 150 (37 ) 113 Additions to oil and gas property (4,578 ) 370 (4,208 ) Net cash used in investing activities - continuing operations (3,659 ) 370 (3,289 ) Net cash provided by investing activities - discontinued operations 4,335 37 4,372 NET INCREASE (DECREASE) IN CASH 698 90 788 BEGINNING CASH BALANCE 769 (90 ) 679 ENDING CASH BALANCE 1,467 — 1,467 Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ (5,060 ) $ (2,959 ) $ (8,019 ) Loss (income) from discontinued operations 1,588 119 1,707 Loss (gain) on divestitures, net 180 1,428 1,608 Exploratory dry hole expense and unproved leasehold impairments — 2,294 2,294 Depreciation, depletion, and amortization 9,720 (5,194 ) 4,526 Impairments 1,919 5,183 7,102 Provision for (benefit from) deferred income taxes (514 ) (1,285 ) (1,799 ) Changes in operating assets and liabilities (239 ) (90 ) (329 ) Net cash provided by operating activities - continuing operations 7,517 (504 ) 7,013 Net cash provided by operating activities - discontinued operations 944 — 944 Additions to oil and gas property (9,022 ) 414 (8,608 ) Net cash used in investing activities - continuing operations (8,585 ) 414 (8,171 ) Net cash used in investing activities - discontinued operations (219 ) — (219 ) NET INCREASE (DECREASE) IN CASH (1,137 ) (90 ) (1,227 ) BEGINNING CASH BALANCE 1,906 — 1,906 ENDING CASH BALANCE 769 (90 ) 679 Changes to the Statement of Consolidated Cash Flows For the Year Ended December 31, 2013 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Net income (loss) including noncontrolling interest $ 2,288 $ (1,844 ) $ 444 Loss (income) from discontinued operations (308 ) (130 ) (438 ) Loss (gain) on divestitures, net — 1,231 1,231 Exploratory dry hole expense and unproved leasehold impairments — 729 729 Depreciation, depletion, and amortization 5,866 (809 ) 5,057 Impairments — 1,443 1,443 Provision for (benefit from) deferred income taxes 309 (1,041 ) (732 ) Net cash provided by operating activities - continuing operations 8,685 (421 ) 8,264 Net cash provided by operating activities - discontinued operations 1,150 14 1,164 Additions to oil and gas property (8,663 ) 421 (8,242 ) Net cash used in investing activities - continuing operations (5,256 ) 421 (4,835 ) Net cash used in investing activities - discontinued operations (1,860 ) (14 ) (1,874 ) NET INCREASE (DECREASE) IN CASH 1,746 — 1,746 BEGINNING CASH BALANCE 160 — 160 ENDING CASH BALANCE 1,906 — 1,906 The following tables present the effects of the change to the successful efforts method in the consolidated balance sheet: Changes to the Consolidated Balance Sheet December 31, 2015 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) PROPERTY AND EQUIPMENT: Property and equipment - cost $ 93,825 $ (47,675 ) $ 46,150 Less: Accumulated depreciation, depletion, and amortization (79,706 ) 54,394 (25,312 ) PROPERTY AND EQUIPMENT, NET 14,119 6,719 20,838 TOTAL ASSETS 18,781 6,719 25,500 Income taxes 1,072 1,457 2,529 Paid-in capital 12,467 152 12,619 Accumulated deficit (1) (7,153 ) 5,173 (1,980 ) Accumulated other comprehensive loss (116 ) (3 ) (119 ) Noncontrolling interest 1,662 (60 ) 1,602 TOTAL EQUITY 4,228 5,262 9,490 Changes to the Consolidated Balance Sheet December 31, 2014 Under Full Cost Changes* As Reported Under Successful Efforts (In millions) Cash and cash equivalents $ 769 $ (90 ) $ 679 Receivables, net of allowance 2,024 (5 ) 2,019 Inventories 708 (27 ) 681 Drilling advances 388 (105 ) 283 Current assets held for sale 1,628 1,753 3,381 Deferred tax asset 769 121 890 PROPERTY AND EQUIPMENT: Property and equipment - cost 103,458 (42,000 ) 61,458 Less: Accumulated depreciation, depletion, and amortization (55,382 ) 28,569 (26,813 ) PROPERTY AND EQUIPMENT, NET 48,076 (13,431 ) 34,645 Deferred charges and other 1,394 163 1,557 TOTAL ASSETS 55,885 (11,621 ) 44,264 Accounts payable 1,210 (100 ) 1,110 Current liabilities held for sale 19 409 428 Other current liabilities 2,435 (195 ) 2,240 Income taxes 9,499 (4,006 ) 5,493 Noncurrent asset retirement obligations 3,048 (133 ) 2,915 Paid-in capital 12,438 152 12,590 Retained earnings (1) 16,249 (7,594 ) 8,655 Noncontrolling interest 2,200 (154 ) 2,046 TOTAL EQUITY 28,137 (7,596 ) 20,541 *In conjunction with recasting the financial information for the adoption of the successful efforts method of accounting, we corrected certain immaterial errors in the North Sea pertaining to the improper calculation of deferred tax liabilities associated with capitalized interest under the full cost method. (1) The cumulative effect of the change to the successful efforts method on retained earnings (accumulated deficit) as of January 1, 2013 was a decrease of $2.8 billion .

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables) - Divestiture [Member]	12 Months Ended
	Dec. 31, 2015
Argentina [Member]
Summary of Sales and Other Operating Revenue and Loss from Discontinued Operation Related to Disposition	For the Year Ended December 31, 2015 2014 2013 (In millions) Revenues and other from discontinued operations $ — $ 87 $ 494 Loss from Argentina divestiture — (654 ) — Income (loss) from operations in Argentina — (1 ) (90 ) Income tax benefit — 23 — Income (loss) from discontinued operations, net of tax $ — $ (632 ) $ (90 )
Australia [Member]
Summary of Carrying Amount of Major Assets and Liabilities Associated with Disposition	December 31, 2014 (In millions) ASSETS Current assets held for sale $ 3,019 Other current assets 590 Oil and gas assets, net 1,613 GTP and other assets, net 877 Total assets $ 6,099 LIABILITIES Current liabilities held for sale $ 321 Other current liabilities 318 Asset retirement obligations 466 Non-current deferred tax liability 329 Other long-term liabilities 33 Total liabilities $ 1,467
Summary of Sales and Other Operating Revenue and Loss from Discontinued Operation Related to Disposition	For the Year Ended December 31, 2015 2014 2013 (In millions) Revenues and other from discontinued operations $ 288 $ 1,050 $ 1,121 Impairment on Woodside sale $ (49 ) $ (833 ) $ — Loss on Consortium sale (139 ) — — Income (loss) from divested Australian operations 28 (12 ) 550 Income tax benefit (expense) 652 (231 ) (22 ) Income (loss) from Australian discontinued operations, net of tax $ 492 $ (1,076 ) $ 528

Capitalized Exploratory Well 31

Capitalized Exploratory Well Costs (Tables)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Capitalized Exploratory Well Costs, Roll Forward	The following summarizes the changes in capitalized exploratory well costs for each of the last three years ended December 31, 2015 , 2014 , and 2013 . Additions pending the determination of proved reserves excludes amounts capitalized and subsequently charged to expense within the same year. 2015 2014 2013 (In millions) Balance at January 1 $ 849 $ 630 $ 546 Additions pending determination of proved reserves 382 622 549 Divestitures and other (557 ) (54 ) (136 ) Reclassifications to proved properties (369 ) (207 ) (244 ) Charged to exploration expense (60 ) (142 ) (85 ) Balance at December 31 (1) $ 245 $ 849 $ 630 (1) Includes $49 million of assets that were held for sale in Australia at December 31, 2014.
Schedule of Aging of Capitalized Exploratory Well Costs	The following provides an aging of capitalized exploratory well costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year since the completion of drilling: 2015 2014 2013 (In millions) Exploratory well costs capitalized for a period of one year or less $ 184 $ 504 $ 350 Exploratory well costs capitalized for a period greater than one year 61 345 280 Balance at December 31 (1) $ 245 $ 849 $ 630 Number of projects with exploratory well costs capitalized for a period greater than one year 2 18 30 (1) Includes $49 million of assets that were held for sale in Australia at December 31, 2014.
Schedule of Projects with Exploratory Well Costs Capitalized for More than One Year	The following summarizes a further aging by geographic area of those exploratory well costs that have been capitalized for a period greater than one year since the completion of drilling at December 31, 2015 : 2012 and Total 2014 2013 Prior North Sea $ 61 $ 3 $ — $ 58 $ 61 $ 3 $ — $ 58

Derivative Instruments and He32

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Activity Recorded in Statement of Consolidated Operations	Gain (Loss) on Derivatives Recognized in Income For the Year Ended December 31, 2015 2014 2013 (In millions) Loss on cash flow hedges reclassified from accumulated other comprehensive loss Oil and Gas Production Revenues $ — $ — $ (16 ) Loss for ineffectiveness on cash flow hedges Revenues and Other: Other — — (1 ) Derivatives not designated as cash flow hedges: Realized loss — (16 ) (178 ) Unrealized gain (loss) — 300 (221 ) Gain (loss) on derivatives not designated as cash flow hedges Revenues and Other: Other $ — $ 284 $ (399 )

Other Current Liabilities (Tabl

Other Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Detail of Other Current Liabilities	h

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	2015 2014 (In millions) Asset retirement obligation at beginning of year $ 2,952 $ 3,222 Liabilities incurred 68 171 Liabilities divested (490 ) (471 ) Liabilities settled (90 ) (146 ) Accretion expense 158 181 Revisions in estimated liabilities — 128 Liabilities held for sale (1) — (133 ) Asset retirement obligation at end of year 2,598 2,952 Less current portion (36 ) (37 ) Asset retirement obligation, long-term $ 2,562 $ 2,915

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Debt for Apache and Subsidiaries	December 31, 2015 2014 (In millions) U.S.: Commercial paper $ — $ 1,570 5.625% notes due 2017 (1) — 500 1.75% notes due 2017 (1) — 400 6.9% notes due 2018 (1) 400 400 7.0% notes due 2018 150 150 7.625% notes due 2019 150 150 3.625% notes due 2021 (1) 500 500 3.25% notes due 2022 (1) 919 919 2.625% notes due 2023 (1) 531 531 7.7% notes due 2026 100 100 7.95% notes due 2026 180 180 6.0% notes due 2037 (1) 1,000 1,000 5.1% notes due 2040 (1) 1,500 1,500 5.25% notes due 2042 (1) 500 500 4.75% notes due 2043 (1) 1,500 1,500 4.25% notes due 2044 (1) 800 800 7.375% debentures due 2047 150 150 7.625% debentures due 2096 150 150 8,530 11,000 Subsidiary and other obligations: Notes due in 2016 and 2017 1 1 Apache Finance Canada 7.75% notes due 2029 300 300 301 301 Debt before unamortized discount and debt issuance costs 8,831 11,301 Unamortized discount (53 ) (56 ) Debt issuance costs (61 ) (67 ) Total debt 8,717 11,178 Current maturities (1 ) — Long-term debt $ 8,716 $ 11,178 (1) These notes are redeemable, as a whole or in part, at Apache’s option, subject to a make-whole premium. The remaining notes and debentures are not redeemable.
Schedule of Long Term Debt by Maturity	(In millions) 2016 and 2017 $ 1 2018 550 2019 150 Thereafter 8,130 Total Debt, excluding discounts and debt issuance costs $ 8,831
Summary of Carrying Amounts and Estimated Fair Values	December 31, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Commercial paper $ — $ — $ 1,570 $ 1,570 Notes and debentures 8,717 8,330 9,608 9,944 Total Debt $ 8,717 $ 8,330 $ 11,178 $ 11,514
Components of Financing Costs, Net	For the Year Ended December 31, 2015 2014 2013 (In millions) Interest expense $ 486 $ 499 $ 560 Amortization of deferred loan costs 11 6 8 Capitalized interest (15 ) (85 ) (99 ) Loss (gain) on extinguishment of debt 39 — (16 ) Interest income (10 ) (7 ) (8 ) Financing costs, net $ 511 $ 413 $ 445

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income (Loss) Before Income Taxes	For the Year Ended December 31, 2015 2014 2013 (In millions) U.S. $ (9,386 ) $ (4,807 ) $ (1,166 ) Foreign (2,783 ) (2,023 ) 2,113 Total $ (12,169 ) $ (6,830 ) $ 947
Total Provision for Income Taxes	For the Year Ended December 31, 2015 2014 2013 (In millions) Current taxes: Federal $ 363 $ (10 ) $ (29 ) State 41 1 — Foreign 31 1,290 1,702 435 1,281 1,673 Deferred taxes: Federal (1,123 ) (671 ) (83 ) State (51 ) (45 ) 17 Foreign (271 ) (1,083 ) (666 ) (1,445 ) (1,799 ) (732 ) Total $ (1,010 ) $ (518 ) $ 941
Reconciliation of Tax of Income Before Income Taxes and Total Tax Expense	For the Year Ended December 31, 2015 2014 2013 (In millions) Income tax expense (benefit) at U.S. statutory rate $ (4,259 ) $ (2,391 ) $ 331 State income tax, less federal benefit (7 ) (28 ) 12 Taxes related to foreign operations (662 ) (147 ) 89 Tax credits (6 ) — 6 Tax on distributed foreign earnings 726 311 225 Foreign tax credit carryforwards (2,090 ) — — Deferred tax on undistributed foreign earnings 1,903 560 — Tax impact of goodwill adjustments 82 161 221 Change in U.K. tax rate (414 ) — — Net change in tax contingencies 20 (3 ) (10 ) Valuation allowances 3,746 1,021 125 All other, net (49 ) (2 ) (58 ) $ (1,010 ) $ (518 ) $ 941
Net Deferred Tax Liability	December 31, 2015 2014 (In millions) Deferred tax assets: Deferred income $ 20 $ — U.S. and state net operating loss carryforwards 329 1,333 Foreign net operating loss carryforwards 1,507 366 Tax credits and other tax incentives 82 42 Foreign tax credit carryforwards 2,090 — Accrued expenses and liabilities 136 68 Asset retirement obligation 1,037 1,202 Property and equipment 1,529 856 Total deferred tax assets 6,730 3,867 Valuation allowance (5,434 ) (1,564 ) Net deferred tax assets 1,296 2,303 Deferred tax liabilities: Other 4 19 Deferred income 140 24 Investment in foreign subsidiaries 1,903 1,119 Property and equipment 1,773 5,755 Total deferred tax liabilities 3,820 6,917 Net deferred income tax liability $ 2,524 $ 4,614
Net Deferred Tax Assets and Liabilities	December 31, 2015 2014 (In millions) Assets: Deferred tax asset $ — $ (890 ) Deferred charges and other (5 ) (17 ) Liabilities Other current liabilities — 28 Deferred income taxes 2,529 5,493 Net deferred income tax liability $ 2,524 $ 4,614
Summary of Valuation Allowance Against Certain Foreign Net Deferred Tax Assets and State Net Operating Losses	2015 2014 2013 (In millions) Balance at beginning of year $ 1,564 $ 598 $ 375 State (1) 151 62 30 U.S. 2,159 — — Foreign (2) 1,560 1,021 125 Discontinued operations (3) — (117 ) 68 Balance at end of year $ 5,434 $ 1,564 $ 598
Net Operating Losses	Amount Expiration (In millions) Net operating losses: U.S. $ 198 2018 - 2035 State 3,496 Various Canada 60 2028 - 2035
Schedule of Foreign Tax Credit Carryforward	Amount Expiration (In millions) Foreign Tax Credits $ 2,090 2025-2026
Reconciliation of Beginning and Ending Amount of Unrecognized Tax Benefits	2015 2014 2013 (In millions) Balance at beginning of year $ — $ 3 $ 3 Additions based on tax positions related to the current year 19 — — Reductions for tax positions of prior years — (3 ) — Balance at end of year $ 19 $ — $ 3
Key Jurisdictions of Company's Earliest Open Tax Years	U.S. 2011 Canada 2011 Egypt 1998 U.K. 2013

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Contractual Obligations	Net Minimum Commitments Total 2016 2017-2018 2019-2020 2021 & Beyond (In millions) Drilling rig commitments $ 405 $ 194 $ 211 $ — $ — Purchase obligations (1) 354 28 115 139 72 Firm transportation agreements 363 96 125 83 59 Office and related equipment 342 43 87 72 140 Other operating lease obligations (2) 64 22 35 6 1 Total Net Minimum Commitments $ 1,528 $ 383 $ 573 $ 300 $ 272

Retirement and Deferred Compe38

Retirement and Deferred Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Changes in Benefit Obligation, Fair Value of Plan Assets and Funded Status of Pension and Postretirement Benefit Plans	The following tables set forth the benefit obligation, fair value of plan assets and funded status as of December 31, 2015, 2014, and 2013, and the underlying weighted average actuarial assumptions used for the U.K. Pension Plan and U.S. postretirement benefit plan. Apache uses a measurement date of December 31 for its pension and postretirement benefit plans. 2015 2014 2013 Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits (In millions) Change in Projected Benefit Obligation Projected benefit obligation beginning of year $ 216 $ 22 $ 189 $ 28 $ 177 $ 35 Service cost 5 2 5 3 5 4 Interest cost 8 1 9 1 7 1 Foreign currency exchange rate changes (10 ) — (13 ) — 4 — Actuarial losses (gains) (10 ) — 31 (9 ) — (8 ) Effect of curtailment and settlements — 2 — — — (3 ) Benefits paid (7 ) (2 ) (5 ) (2 ) (4 ) (2 ) Retiree contributions — 1 — 1 — 1 Projected benefit obligation at end of year 202 26 216 22 189 28 Change in Plan Assets Fair value of plan assets at beginning of year 206 — 191 — 170 — Actual return on plan assets 1 — 25 — 15 — Foreign currency exchange rates (10 ) — (13 ) — 4 — Employer contributions 7 1 8 1 6 1 Benefits paid (7 ) (2 ) (5 ) (2 ) (4 ) (2 ) Retiree contributions — 1 — 1 — 1 Fair value of plan assets at end of year 197 — 206 — 191 — Funded status at end of year $ (5 ) $ (26 ) $ (10 ) $ (22 ) $ 2 $ (28 ) Amounts recognized in Consolidated Balance Sheet Current liability $ — $ (2 ) $ — $ (1 ) $ — $ (1 ) Non-current asset (liability) (5 ) (24 ) (10 ) (21 ) 2 (27 ) $ (5 ) $ (26 ) $ (10 ) $ (22 ) $ 2 $ (28 ) Pre-tax Amounts Recognized in Accumulated Other Comprehensive Income (Loss) Accumulated gain (loss) $ (32 ) $ 9 $ (37 ) $ 10 $ (22 ) $ 1 Weighted Average Assumptions used as of December 31 Discount rate 3.90 % 3.95 % 3.70 % 3.62 % 4.60 % 4.33 % Salary increases 4.60 % N/A 4.60 % N/A 4.90 % N/A Expected return on assets 4.10 % N/A 3.90 % N/A 5.60 % N/A Healthcare cost trend Initial N/A 7.00 % N/A 7.00 % N/A 7.00 % Ultimate in 2025 N/A 5.00 % N/A 5.00 % N/A 5.00 %
Allocations for Plan Asset Holding and Target Allocation for Company's Plan Asset	A breakout of previous allocations for plan asset holdings and the target allocation for the Company’s plan assets are summarized below: Target Allocation Percentage of Plan Assets at Year-End 2015 2015 2014 Asset Category Equity securities: U.K. quoted equities 14 % 14 % 14 % Overseas quoted equities 26 % 26 % 26 % Total equity securities 40 % 40 % 40 % Debt securities: U.K. Government bonds 48 % 48 % 48 % U.K. corporate bonds 12 % 12 % 12 % Debt securities 60 % 60 % 60 % Total 100 % 100 % 100 %
Fair Values of Plan Assets for Each Major Asset Category Based on Nature and Significant Concentration of Risks in Plan Assets	The following tables present the fair values of plan assets for each major asset category based on the nature and significant concentration of risks in plan assets at December 31, 2015 and December 31, 2014: Fair Value Measurements Using: Quoted Price in Active Markets (Level 1) Significant Other Inputs (Level 2) Unobservable Inputs (Level 3) Total Fair Value (In millions) December 31, 2015 Equity securities: U.K. quoted equities (1) $ 27 $ — $ — $ 27 Overseas quoted equities (2) 53 — — 53 Total equity securities 80 — — 80 Debt securities: U.K. Government bonds (3) 93 — — 93 U.K. corporate bonds (4) 24 — — 24 Total debt securities 117 — — 117 Fair value of plan assets $ 197 $ — $ — $ 197 December 31, 2014 Equity securities: U.K. quoted equities (1) $ 28 $ — $ — $ 28 Overseas quoted equities (2) 54 — — 54 Total equity securities 82 — — 82 Debt securities: U.K. Government bonds (3) 99 — — 99 U.K. corporate bonds (4) 25 — — 25 Total debt securities 124 — — 124 Fair value of plan assets $ 206 $ — $ — $ 206 (1) This category comprises U.K. passive equities, which are benchmarked against the FTSE 350 Index. (2) This category includes overseas equities, which comprises 30.3 percent passive global equities benchmarked against the MSCI World (NDR) Index, 12.1 percent passive global equities (hedged) benchmarked against the MSCI World (NDR) Hedged Index, 30.3 percent fundamental indexation global equities benchmarked against the FTSE RAFI Developed 1000 index, 12.1 percent fundamental indexation global equities (hedged) benchmarked against the FTSE RAFI Developed 1000 Hedge Index, and 15.2 percent emerging markets benchmarked against the MSCI Emerging Markets (NDR) Index, which has a performance target of 2 percent per annum over the benchmark over a rolling three -year period. (3) This category includes U.K. Government bonds, which comprises 48 percent index-linked gilts benchmarked against the FTSE Actuaries Government Securities Index-Linked Over 5 Years Index, 37 percent sterling nominal LDI bonds, and 15 percent sterling inflation linked LDI bonds, both benchmarked against ILIM Custom Benchmark index. (4) This category comprises U.K. corporate bonds: 12 percent benchmarked against the BofAML Sterling Corporate & Collaterlised (excluding Subordinated) Index with a performance target of 0.75 percent per annum over the benchmark over a rolling five -year period.
Components of Net Periodic Cost and Underlying Weighted Average Actuarial Assumptions Used for Pension and Postretirement Benefit Plans	The following tables set forth the components of the net periodic cost and the underlying weighted average actuarial assumptions used for the pension and postretirement benefit plans as of December 31, 2015, 2014, and 2013: 2015 2014 2013 Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits (In millions) Component of Net Periodic Benefit Costs Service cost $ 5 $ 2 $ 5 $ 3 $ 5 $ 4 Interest cost 8 1 9 1 7 1 Expected return on assets (8 ) — (11 ) — (8 ) — Amortization of actuarial (gain) loss 2 — 1 — 2 — Curtailment (gain) loss — — — — — (3 ) Net periodic benefit cost $ 7 $ 3 $ 4 $ 4 $ 6 $ 2 Weighted Average Assumptions used to determine Net Period Benefit Cost for the Years ended December 31 Discount rate 3.70 % 3.62 % 4.60 % 4.33 % 4.30 % 3.43 % Salary increases 4.60 % N/A 4.90 % N/A 4.60 % N/A Expected return on assets 3.90 % N/A 5.60 % N/A 4.70 % N/A Healthcare cost trend Initial N/A 7.00 % N/A 7.00 % N/A 7.25 % Ultimate in 2025 N/A 5.00 % N/A 5.00 % N/A 5.00 %
Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	A one-percentage-point change in assumed health care cost trend rates would have the following effects: Postretirement Benefits 1% Increase 1% Decrease (In millions) Effect on service and interest cost components $ 1 $ (1 ) Effect on postretirement benefit obligation 4 (3 )
Expected Future Benefit Payment	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid: Pension Benefits Postretirement Benefits (In millions) 2016 $ 4 $ 2 2017 4 2 2018 4 2 2019 4 2 2020 4 2 Years 2021-2025 22 10

Capital Stock (Tables)

Capital Stock (Tables)	12 Months Ended
	Dec. 31, 2015
Common Stock Outstanding	Common Stock Outstanding 2015 2014 2013 Balance, beginning of year 376,504,892 395,772,908 391,640,770 Shares issued for stock-based compensation plans: Treasury shares issued 17,525 17,454 25,214 Common shares issued 1,511,758 1,665,259 929,596 Common shares issued for conversion of preferred shares — — 14,399,247 Treasury shares acquired — (20,950,729 ) (11,221,919 ) Balance, end of year 378,034,175 376,504,892 395,772,908
Net Income Per Common Share	A reconciliation of the components of basic and diluted net income per common share for the years ended December 31, 2015 , 2014 , and 2013 is presented in the table below. 2015 2014 2013 Loss Shares Per Share Loss Shares Per Share Income (Loss) Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ (10,844 ) 378 $ (28.70 ) $ (6,653 ) 384 $ (17.32 ) $ (94 ) 395 $ (0.24 ) Income (loss) from discontinued operations 492 378 1.30 (1,707 ) 384 (4.44 ) 438 395 1.11 Income (loss) attributable to common stock $ (10,352 ) 378 $ (27.40 ) $ (8,360 ) 384 $ (21.76 ) $ 344 395 $ 0.87 Effect of Dilutive Securities: Mandatory Convertible Preferred Stock $ — — $ — — $ — — Stock options and other — — — — — — Diluted: Income (loss) from continuing operations $ (10,844 ) 378 $ (28.70 ) $ (6,653 ) 384 $ (17.32 ) $ (94 ) 395 $ (0.24 ) Income (loss) from discontinued operations 492 378 1.30 (1,707 ) 384 (4.44 ) 438 395 1.11 Income (loss) attributable to common stock $ (10,352 ) 378 $ (27.40 ) $ (8,360 ) 384 $ (21.76 ) $ 344 395 $ 0.87
Description of Stock Based Compensation Plans and Related Costs	A description of the Company’s stock-based compensation plans and related costs follows: 2015 2014 2013 (In millions) Stock-based compensation expensed: General and administrative $ 64 $ 107 $ 89 Lease operating expenses 36 41 47 Stock-based compensation for exploration and development activities 53 62 55 $ 153 $ 210 $ 191
Summary of Stock Options Issued Under Stock Option Plans	A summary of stock options issued and outstanding under the Stock Option Plans and the Omnibus Plans is presented in the table and narrative below: 2015 Shares Under Option Weighted Average Exercise Price (In thousands) Outstanding, beginning of year 6,445 $ 90.34 Granted — — Exercised (280 ) 56.72 Forfeited or expired (1,234 ) 93.28 Outstanding, end of year (1) 4,931 91.52 Expected to vest (1) 566 81.77 Exercisable, end of year (1) 4,311 92.92 (1) As of December 31, 2015, the weighted average remaining contractual life for options outstanding, expected to vest, and exercisable is 4.5 years, 6.9 years, and 4.1 years, respectively. The aggregate intrinsic value of options outstanding, expected to vest, and exercisable at year-end was nil.
Summary of Restricted Stock Activity	A summary of restricted stock activity for the year ended December 31, 2015, is presented below. Shares Weighted- Average Grant- Date Fair Value (In thousands) Non-vested at January 1, 2015 4,784 $ 81.96 Granted 2,976 61.65 Vested (1,839 ) 81.14 Forfeited (1,351 ) 78.26 Non-vested at December 31, 2015 4,570 70.12
Business Performance Program [Member]
Summary of Restricted Stock Activity	Shares Weighted Average Grant- Date Fair Value (1) (In thousands) Non-vested at January 1, 2015 — $ — Granted 602 66.63 Vested — — Forfeited or expired (101 ) 66.63 Non-vested at December 31, 2015 501 66.63 (1) The fair value of each conditional restricted stock unit award is estimated as of the date of grant using a Monte Carlo simulation with the following assumptions used for all grants made under the plan: (i) a three-year continuous risk-free interest rate; (ii) a constant volatility assumption based on the historical realized stock price volatility of the Company and the designated peer group; and (iii) the historical stock prices and expected dividends of the common stock of the Company and its designated peer group.

Accumulated Other Comprehensi40

Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Components of Accumulated Other Comprehensive Income (Loss)	For the Year Ended December 31, 2015 2014 2013 (In millions) Currency translation adjustment (1) $ (109 ) $ (109 ) $ (109 ) Unrealized gain (loss) on derivatives (Note 5) — — 1 Unfunded pension and postretirement benefit plan (Note 11) (10 ) (7 ) (7 ) Accumulated other comprehensive loss $ (119 ) $ (116 ) $ (115 ) (1) Currency translation adjustments resulting from translating the Canadian subsidiaries’ financial statements into U.S. dollar equivalents, prior to adoption of the U.S. dollar as their functional currency, were reported separately and accumulated in other comprehensive income (loss).

Business Segment Information (T

Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Financial Segment Information	United States Canada Egypt (1) North Sea Other International Total (1) (In millions) 2015 Oil and gas production revenues $ 2,637 $ 498 $ 2,095 $ 1,280 $ — $ 6,510 Operating Expenses: Depreciation, depletion, and amortization 1,558 301 927 514 — 3,300 Exploration 2,145 231 154 237 4 2,771 Asset retirement obligation accretion 28 43 — 74 — 145 Lease operating expenses 739 244 522 349 — 1,854 Gathering and transportation 68 89 45 9 — 211 Taxes other than income 184 26 9 63 — 282 Impairments 6,266 1,593 1,255 211 147 9,472 Operating Income (Loss) $ (8,351 ) $ (2,029 ) $ (817 ) $ (177 ) $ (151 ) (11,525 ) Other Income (Expense): Gain (loss) on divestitures, net 281 Other 98 General and administrative (380 ) Transaction, reorganization, and separation (132 ) Financing costs, net (511 ) Net Loss From Continuing Operations Before Income Taxes $ (12,169 ) Net Property and Equipment $ 11,753 $ 2,074 $ 3,712 $ 3,263 $ 36 $ 20,838 Total Assets $ 12,782 $ 2,225 $ 6,165 $ 4,280 $ 48 $ 25,500 Additions to Net Property and Equipment $ 2,099 $ 403 $ 862 $ 715 $ 27 $ 4,106 United States Canada Egypt (1) North Sea Other International Total (1) (In millions) 2014 Oil and gas production revenues (2) $ 5,744 $ 1,092 $ 3,643 $ 2,316 $ — $ 12,795 Operating Expenses: Depreciation, depletion, and amortization 2,408 439 872 807 — 4,526 Exploration 2,113 162 112 119 (7 ) 2,499 Asset retirement obligation accretion 43 39 — 72 — 154 Lease operating expenses 921 384 499 434 — 2,238 Gathering and transportation 93 123 40 17 — 273 Taxes other than income 350 31 11 185 — 577 Impairments 2,622 2,412 173 1,895 — 7,102 Operating Income (Loss) (2) $ (2,806 ) $ (2,498 ) $ 1,936 $ (1,213 ) $ 7 (4,574 ) Other Income (Expense): Gain (loss) on divestitures, net (1,608 ) Other 285 General and administrative (453 ) Transaction, reorganization, and separation (67 ) Financing costs, net (413 ) Net Income From Continuing Operations Before Income Taxes (2) $ (6,830 ) Net Property and Equipment (2) $ 19,507 $ 4,197 $ 5,141 $ 3,300 $ 9 $ 32,154 Total Assets (2) $ 21,487 $ 4,728 $ 6,926 $ 4,480 $ 544 $ 38,165 Additions to Net Property and Equipment (2) $ 7,006 $ 1,358 $ 1,293 $ 1,060 $ 8 $ 10,725 2013 Oil and gas production revenues (2) $ 6,902 $ 1,224 $ 3,971 $ 2,728 $ — $ 14,825 Operating Expenses: Depreciation, depletion, and amortization 2,690 510 880 976 1 5,057 Exploration 629 86 86 58 83 942 Asset retirement obligation accretion 94 49 — 68 — 211 Lease operating expenses 1,320 459 471 400 — 2,650 Gathering and transportation 84 155 42 7 — 288 Taxes other than income 335 45 8 384 — 772 Impairments 96 274 12 1,061 — 1,443 Operating Income (Loss) (2) $ 1,654 $ (354 ) $ 2,472 $ (226 ) $ (84 ) 3,462 Other Income (Expense): Gain (loss) on divestitures, net (1,231 ) Other (315 ) General and administrative (491 ) Transaction, reorganization, and separation (33 ) Financing costs, net (445 ) Net Income From Continuing Operations Before Income Taxes (2) $ 947 Net Property and Equipment (2) $ 23,440 $ 6,300 $ 4,908 $ 5,064 $ 1 $ 39,713 Total Assets (2) $ 25,488 $ 7,191 $ 7,761 $ 6,334 $ 487 $ 47,261 Additions to Net Property and Equipment (2) $ 6,159 $ 1,065 $ 1,226 $ 1,078 $ 1 $ 9,529 (1) Includes a noncontrolling interest in Egypt. (2) Prior year amounts have been recast to exclude discontinued operations.

Supplemental Oil and Gas Disc42

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Revenue and Direct Cost Information Relating to Company's Oil and Gas Exploration and Production Activities	United States Canada Egypt (3) North Sea Other International Total (3)(4) (In millions, except per boe) 2015 Oil and gas production revenues $ 2,637 $ 498 $ 2,095 $ 1,280 $ — $ 6,510 Operating cost: Depreciation, depletion, and amortization (1) 1,455 251 780 490 — 2,976 Asset retirement obligation accretion 28 43 — 74 — 145 Lease operating expenses 739 244 522 349 — 1,854 Gathering and transportation 68 89 45 9 — 211 Exploration expenses 2,145 231 154 237 4 2,771 Impairments related to oil and gas properties 6,154 1,031 193 11 — 7,389 Production taxes (2) 178 23 — 58 — 259 Income tax (2,886 ) (369 ) 180 26 — (3,049 ) 7,881 1,543 1,874 1,254 4 12,556 Results of operation $ (5,244 ) $ (1,045 ) $ 221 $ 26 $ (4 ) $ (6,046 ) 2014 Oil and gas production revenues $ 5,744 $ 1,092 $ 3,643 $ 2,316 $ — $ 12,795 Operating cost: Depreciation, depletion, and amortization (1) 2,294 382 735 784 — 4,195 Asset retirement obligation accretion 43 39 — 72 — 154 Lease operating expenses 921 384 499 434 — 2,238 Gathering and transportation 93 123 40 17 — 273 Exploration expenses 2,113 162 112 119 (7 ) 2,499 Impairments related to oil and gas properties 2,372 1,645 173 1,878 — 6,068 Production taxes (2) 342 27 — 177 — 546 Income tax (864 ) (421 ) 938 (723 ) — (1,070 ) 7,314 2,341 2,497 2,758 (7 ) 14,903 Results of operation $ (1,570 ) $ (1,249 ) $ 1,146 $ (442 ) $ 7 $ (2,108 ) 2013 Oil and gas production revenues $ 6,902 $ 1,224 $ 3,971 $ 2,728 $ — $ 14,825 Operating cost: Depreciation, depletion, and amortization (1) 2,579 417 756 953 — 4,705 Asset retirement obligation accretion 94 49 — 68 — 211 Lease operating expenses 1,320 459 471 400 — 2,650 Gathering and transportation 84 155 42 7 — 288 Exploration expenses 629 86 86 58 83 942 Impairments related to oil and gas properties 96 274 12 1,061 — 1,443 Production taxes (2) 324 40 — 382 — 746 Income tax 630 (63 ) 1,198 (125 ) — 1,640 5,756 1,417 2,565 2,804 83 12,625 Results of operation $ 1,146 $ (193 ) $ 1,406 $ (76 ) $ (83 ) $ 2,200 (1) This amount only reflects DD&A of capitalized costs of oil and gas properties and, therefore, does not agree with DD&A reflected on Note 15—Business Segment Information. (2) Only reflects amounts directly related to oil and gas producing properties and, therefore, does not agree with taxes other than income reflected on Note 15—Business Segment Information. (3) Includes noncontrolling interest in Egypt. (4) Prior year amounts have been recast to exclude discontinued operations.
Costs Incurred in Oil and Gas Property Acquisitions, Exploration and Development Activities	Costs Incurred in Oil and Gas Property Acquisitions, Exploration, and Development Activities United States Canada Egypt (2) Australia North Sea Argentina Other International Total (2) (In millions) 2015 Acquisitions: Proved $ 1 $ 8 $ 29 $ — $ — $ — $ — $ 38 Unproved 313 23 — — — — — 336 Exploration 194 51 125 32 246 — 29 677 Development 1,729 151 741 98 479 — — 3,198 Costs incurred (1) $ 2,237 $ 233 $ 895 $ 130 $ 725 $ — $ 29 $ 4,249 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ — $ — $ 8 $ 6 $ 7 $ — $ — $ 21 Asset retirement costs 123 8 — — (66 ) — — 65 2014 Acquisitions: Proved $ 102 $ — $ 11 $ — $ — $ — $ — $ 113 Unproved 1,221 141 — 16 — — — 1,378 Exploration 505 93 207 131 103 9 1 1,049 Development 5,078 789 1,122 990 956 6 — 8,941 Costs incurred (1) $ 6,906 $ 1,023 $ 1,340 $ 1,137 $ 1,059 $ 15 $ 1 $ 11,481 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ 17 $ — $ 9 $ 90 $ 29 $ 3 $ — $ 148 Asset retirement costs 43 175 — 55 34 — — 307 2013 Acquisitions: Proved $ 17 $ — $ 39 $ — $ 125 $ — $ — $ 181 Unproved 195 151 11 — 17 11 — 385 Exploration 617 35 565 168 259 42 22 1,708 Development 5,188 681 599 1,055 661 142 — 8,326 Costs incurred (1) $ 6,017 $ 867 $ 1,214 $ 1,223 $ 1,062 $ 195 $ 22 $ 10,600 (1) Includes capitalized interest and asset retirement costs as follows: Capitalized interest $ 50 $ — $ 2 $ 74 $ 32 $ 10 $ — $ 168 Asset retirement costs 480 17 — (30 ) 67 3 — 537 (2) Includes a noncontrolling interest in Egypt. United States Canada Egypt (1) Australia North Sea Other International Total (1) (In millions) 2015 Proved properties $ 18,692 $ 5,812 $ 9,798 $ — $ 7,426 $ — $ 41,728 Unproved properties 1,615 172 25 — 429 36 2,277 20,307 5,984 9,823 — 7,855 36 44,005 Accumulated DD&A (9,027 ) (3,958 ) (6,559 ) — (4,913 ) — (24,457 ) $ 11,280 $ 2,026 $ 3,264 $ — $ 2,942 $ 36 $ 19,548 2014 Proved properties $ 22,791 $ 6,659 $ 9,096 $ 3,919 $ 6,911 $ — $ 49,376 Unproved properties 3,610 675 179 438 579 9 5,490 26,401 7,334 9,275 4,357 7,490 9 54,866 Accumulated DD&A (7,572 ) (3,803 ) (5,779 ) (2,744 ) (4,533 ) — (24,431 ) $ 18,829 $ 3,531 $ 3,496 $ 1,613 $ 2,957 $ 9 $ 30,435 (1) Includes a noncontrolling interest in Egypt.
Proved Reserve Data	Crude Oil and Condensate (Thousands of barrels) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 474,837 79,695 106,746 29,053 119,635 15,845 825,811 December 31, 2013 457,981 80,526 119,242 22,524 100,327 14,195 794,795 December 31, 2014 444,440 75,876 128,712 29,996 105,746 — 784,770 December 31, 2015 348,797 67,847 144,164 — 104,255 — 665,063 Proved undeveloped reserves: December 31, 2012 203,068 70,650 17,288 34,808 28,019 2,981 356,814 December 31, 2013 195,835 56,366 16,302 36,703 29,253 2,231 336,690 December 31, 2014 170,125 59,923 14,617 25,775 19,059 — 289,499 December 31, 2015 60,505 38,326 17,856 — 11,309 — 127,996 Total proved reserves: Balance December 31, 2012 677,905 150,345 124,034 63,861 147,654 18,826 1,182,625 Extensions, discoveries and other additions 133,227 10,177 43,738 2,539 1,543 998 192,222 Purchase of minerals in-place 85 — 5 — 3,623 — 3,713 Revisions of previous estimates 1,683 (531 ) 650 (118 ) 18 24 1,726 Production (53,621 ) (6,469 ) (32,883 ) (7,055 ) (23,258 ) (3,422 ) (126,708 ) Sale of properties (105,463 ) (16,630 ) — — — — (122,093 ) Balance December 31, 2013 653,816 136,892 135,544 59,227 129,580 16,426 1,131,485 Extensions, discoveries and other additions 57,011 9,657 38,074 4,254 17,386 5 126,387 Purchase of minerals in-place 15,240 — — — — — 15,240 Revisions of previous estimates 3,083 (812 ) 2,645 (216 ) (7 ) — 4,693 Production (48,789 ) (6,421 ) (32,934 ) (7,494 ) (22,154 ) (620 ) (118,412 ) Sale of properties (65,796 ) (3,517 ) — — — (15,811 ) (85,124 ) Balance December 31, 2014 614,565 135,799 143,329 55,771 124,805 — 1,074,269 Extensions, discoveries and other additions 13,903 4,550 24,524 — 16,579 — 59,556 Purchase of minerals in-place — 1,763 — — — — 1,763 Revisions of previous estimates (173,907 ) (27,966 ) 27,330 11,189 (2,255 ) — (165,609 ) Production (45,138 ) (5,755 ) (33,163 ) (2,778 ) (21,657 ) — (108,491 ) Sale of properties (121 ) (2,218 ) — (64,182 ) (1,908 ) — (68,429 ) Balance December 31, 2015 409,302 106,173 162,020 — 115,564 — 793,059 (1) 2015, 2014, and 2013 includes proved reserves of 54 MMbbls, 48 MMbbls, and 45 MMbbls, respectively, attributable to a noncontrolling interest in Egypt. Natural Gas Liquids (Thousands of barrels) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 154,508 21,996 — — 2,438 5,007 183,949 December 31, 2013 184,485 26,099 — — 2,435 4,110 217,129 December 31, 2014 183,565 17,947 1,346 — 1,770 — 204,628 December 31, 2015 150,265 15,246 1,491 — 1,784 — 168,786 Proved undeveloped reserves: December 31, 2012 60,889 12,258 — — 380 876 74,403 December 31, 2013 63,538 9,970 — — 215 1,009 74,732 December 31, 2014 69,828 7,168 212 — 371 — 77,579 December 31, 2015 24,939 4,839 78 — 295 — 30,151 Total proved reserves: Balance December 31, 2012 215,397 34,254 — — 2,818 5,883 258,352 Extensions, discoveries and other additions 69,231 4,014 — — — — 73,245 Purchase of minerals in-place 45 — — — 295 — 340 Revisions of previous estimates 1,591 546 — — 1 3 2,141 Production (19,922 ) (2,442 ) — — (464 ) (767 ) (23,595 ) Sale of properties (18,319 ) (303 ) — — — — (18,622 ) Balance December 31, 2013 248,023 36,069 — — 2,650 5,119 291,861 Extensions, discoveries and other additions 47,516 1,163 1,820 — 1 — 50,500 Purchase of minerals in-place 2,916 — — — — — 2,916 Revisions of previous estimates 2,594 116 (11 ) — (2 ) — 2,697 Production (21,464 ) (2,256 ) (251 ) — (508 ) (116 ) (24,595 ) Sale of properties (26,192 ) (9,977 ) — — — (5,003 ) (41,172 ) Balance December 31, 2014 253,393 25,115 1,558 — 2,141 — 282,207 Extensions, discoveries and other additions 5,768 1,473 144 — 689 — 8,074 Purchase of minerals in-place — 976 — — — — 976 Revisions of previous estimates (64,226 ) (4,886 ) 255 — (321 ) — (69,178 ) Production (19,684 ) (2,236 ) (388 ) — (413 ) — (22,721 ) Sale of properties (47 ) (357 ) — — (17 ) — (421 ) Balance December 31, 2015 175,204 20,085 1,569 — 2,079 — 198,937 (1) 2015 and 2014 includes proved reserves of 523 Mbbls and 519 Mbbls, respectively, attributable to a noncontrolling interest in Egypt. Natural Gas (Millions of cubic feet) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 2,353,587 1,734,657 690,436 596,052 93,319 365,054 5,833,105 December 31, 2013 2,005,966 1,294,420 621,825 626,543 88,177 289,133 4,926,064 December 31, 2014 1,616,504 990,145 637,187 640,265 87,259 — 3,971,360 December 31, 2015 1,364,174 759,321 776,263 — 85,532 — 2,985,290 Proved undeveloped reserves: December 31, 2012 832,320 403,227 205,055 1,074,018 18,985 97,496 2,631,101 December 31, 2013 667,160 439,037 190,355 975,224 18,988 121,584 2,412,348 December 31, 2014 580,299 527,623 171,696 964,554 23,228 — 2,267,400 December 31, 2015 208,594 162,809 53,969 — 19,760 — 445,132 Total proved reserves: Balance December 31, 2012 3,185,907 2,137,884 895,491 1,670,070 112,304 462,550 8,464,206 Extensions, discoveries and other additions 306,721 359,493 44,382 13,351 2,750 16,515 743,212 Purchase of minerals in-place 855 — — — 10,680 — 11,535 Revisions of previous estimates 61,247 109,551 14,824 (101 ) 32 49 185,602 Production (285,187 ) (181,593 ) (142,517 ) (81,553 ) (18,601 ) (68,397 ) (777,848 ) Sale of properties (596,417 ) (691,878 ) — — — — (1,288,295 ) Balance December 31, 2013 2,673,126 1,733,457 812,180 1,601,767 107,165 410,717 7,338,412 Extensions, discoveries and other additions 203,318 383,077 125,899 81,156 23,803 — 817,253 Purchase of minerals in-place 21,337 — — — — — 21,337 Revisions of previous estimates 35,910 (12,626 ) 17,326 — (54 ) — 40,556 Production (215,829 ) (117,816 ) (146,522 ) (78,104 ) (20,427 ) (12,722 ) (591,420 ) Sale of properties (521,059 ) (468,324 ) — — — (397,995 ) (1,387,378 ) Balance December 31, 2014 2,196,803 1,517,768 808,883 1,604,819 110,487 — 6,238,760 Extensions, discoveries and other additions 40,901 121,216 94,777 — 41,755 — 298,649 Purchase of minerals in-place — 24,727 — — — — 24,727 Revisions of previous estimates (503,939 ) (325,375 ) 61,442 8,162 (22,373 ) — (782,083 ) Production (160,614 ) (100,289 ) (134,870 ) (34,352 ) (23,647 ) — (453,772 ) Sale of properties (383 ) (315,917 ) — (1,578,629 ) (930 ) — (1,895,859 ) Balance December 31, 2015 1,572,768 922,130 830,232 — 105,292 — 3,430,422 (1) 2015, 2014, and 2013 include proved reserves of 277 Bcf, 270 Bcf, and 271 Bcf, respectively, attributable to a noncontrolling interest in Egypt. Total Equivalent Reserves (Thousands barrels of oil equivalent) United States Canada Egypt (1) Australia North Sea Argentina Total (1) Proved developed reserves: December 31, 2012 1,021,610 390,800 221,819 128,395 137,626 81,695 1,981,945 December 31, 2013 976,795 322,362 222,880 126,948 117,457 66,494 1,832,936 December 31, 2014 897,422 258,848 236,256 136,707 122,058 — 1,651,291 December 31, 2015 726,424 209,647 275,033 — 120,293 — 1,331,397 Proved undeveloped reserves: December 31, 2012 402,677 150,113 51,464 213,811 31,563 20,106 869,734 December 31, 2013 370,566 139,509 48,028 199,240 32,633 23,504 813,480 December 31, 2014 336,670 155,028 43,446 186,534 23,301 — 744,979 December 31, 2015 120,210 70,300 26,929 — 14,897 — 232,336 Total proved reserves: Balance December 31, 2012 1,424,287 540,913 273,283 342,206 169,189 101,801 2,851,679 Extensions, discoveries and other additions 253,578 74,107 51,135 4,764 2,001 3,751 389,336 Purchase of minerals in-place 273 — 5 — 5,698 — 5,976 Revisions of previous estimates 13,482 18,274 3,121 (135 ) 24 35 34,801 Production (121,074 ) (39,177 ) (56,636 ) (20,647 ) (26,822 ) (15,589 ) (279,945 ) Sale of properties (223,185 ) (132,246 ) — — — — (355,431 ) Balance December 31, 2013 1,347,361 461,871 270,908 326,188 150,090 89,998 2,646,416 Extensions, discoveries and other additions 138,413 74,666 60,877 17,780 21,354 5 313,095 Purchase of minerals in-place 21,712 — — — — — 21,712 Revisions of previous estimates 11,662 (2,800 ) 5,522 (216 ) (18 ) — 14,150 Production (106,225 ) (28,313 ) (57,605 ) (20,511 ) (26,067 ) (2,856 ) (241,577 ) Sale of properties (178,831 ) (91,548 ) — — — (87,147 ) (357,526 ) Balance December 31, 2014 1,234,092 413,876 279,702 323,241 145,359 — 2,396,270 Extensions, discoveries and other additions 26,488 26,226 40,464 — 24,227 — 117,405 Purchase of minerals in-place — 6,860 — — — — 6,860 Revisions of previous estimates (322,123 ) (87,081 ) 37,825 12,549 (6,305 ) — (365,135 ) Production (91,591 ) (24,706 ) (56,029 ) (8,503 ) (26,011 ) — (206,840 ) Sale of properties (232 ) (55,228 ) — (327,287 ) (2,080 ) — (384,827 ) Balance December 31, 2015 846,634 279,947 301,962 — 135,190 — 1,563,733 (1) 2015, 2014, and 2013 include total proved reserves of 101 MMboe, 93 MMboe, and 90 MMboe, respectively, attributable to a noncontrolling interest in Egypt.
Unaudited Information of Future Net Cash Flows For Oil and Gas Reserves, Net of Income Tax Expense	United States Canada Egypt (2) Australia North Sea Argentina Total (2) (In millions) 2015 Cash inflows $ 26,610 $ 7,345 $ 11,124 $ — $ 6,994 $ — $ 52,073 Production costs (12,178 ) (3,841 ) (2,185 ) — (3,209 ) — (21,413 ) Development costs (2,255 ) (1,939 ) (1,515 ) — (2,346 ) — (8,055 ) Income tax expense (63 ) — (2,326 ) — (691 ) — (3,080 ) Net cash flows 12,114 1,565 5,098 — 748 — 19,525 10 percent discount rate (6,876 ) (868 ) (1,330 ) — 143 — (8,931 ) Discounted future net cash flows (1) $ 5,238 $ 697 $ 3,768 $ — $ 891 $ — $ 10,594 2014 Cash inflows 73,859 18,966 16,802 19,391 13,916 — 142,934 Production costs (25,875 ) (7,537 ) (2,924 ) (4,105 ) (7,121 ) — (47,562 ) Development costs (4,422 ) (2,453 ) (1,683 ) (1,173 ) (2,776 ) — (12,507 ) Income tax expense (10,657 ) (1,070 ) (4,091 ) (3,202 ) (2,445 ) — (21,465 ) Net cash flows 32,905 7,906 8,104 10,911 1,574 — 61,400 10 percent discount rate (17,639 ) (3,983 ) (2,099 ) (5,875 ) (146 ) — (29,742 ) Discounted future net cash flows (1) $ 15,266 $ 3,923 $ 6,005 $ 5,036 $ 1,428 $ — $ 31,658 (1) Estimated future net cash flows before income tax expense, discounted at 10 percent per annum, totaled approximately $13.1 billion and $43.0 billion as of December 31, 2015 and 2014, respectively. (2) Includes discounted future net cash flows of approximately $1.3 billion and $2.0 billion in 2015 and 2014, respectively, attributable to a noncontrolling interest in Egypt.
Principal Sources of Change In Discounted Future Net Cash Flows	For the Year Ended December 31, 2015 2014 2013 (In millions) Sales, net of production costs $ (4,056 ) $ (10,350 ) $ (12,271 ) Net change in prices and production costs (21,710 ) (1,029 ) 1,438 Discoveries and improved recovery, net of related costs 1,953 6,297 6,892 Change in future development costs 705 (1,136 ) (2,017 ) Previously estimated development costs incurred during the period 1,991 4,462 4,654 Revision of quantities (2,292 ) 256 500 Purchases of minerals in-place 22 508 227 Accretion of discount 3,642 4,442 4,823 Change in income taxes 7,264 836 855 Sales of properties (5,240 ) (4,780 ) (6,232 ) Change in production rates and other (3,343 ) (442 ) (828 ) $ (21,064 ) $ (936 ) $ (1,959 )

Supplemental Quarterly Financ43

Supplemental Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Supplemental Quarterly Financial Data	First Second Third Fourth Total (In millions, except per share amounts) 2015 Revenues and other $ 1,653 $ 2,019 $ 1,531 $ 1,405 $ 6,608 Gain (loss) on divestitures (18 ) 227 (5 ) 77 281 Expenses (1) 2,703 3,163 5,645 6,537 18,048 Net income (loss) from continuing operations including noncontrolling interest (1,068 ) (917 ) (4,119 ) (5,055 ) (11,159 ) Net income (loss) from discontinued operations, net of tax (238 ) 120 (17 ) 627 492 Net income (loss) including noncontrolling interest $ (1,306 ) $ (797 ) $ (4,136 ) $ (4,428 ) $ (10,667 ) Net income (loss) attributable to common stock $ (1,334 ) $ (860 ) $ (4,143 ) $ (4,015 ) $ (10,352 ) Basic net income (loss) per common share (2) : Net income (loss) from continuing operations $ (2.91 ) $ (2.60 ) $ (10.91 ) $ (12.28 ) $ (28.70 ) Net income (loss) from discontinued operations (0.63 ) 0.32 (0.04 ) 1.66 1.30 Net income (loss) per share $ (3.54 ) $ (2.28 ) $ (10.95 ) $ (10.62 ) $ (27.40 ) Diluted net income (loss) per common share (2) : Net income (loss) from continuing operations $ (2.91 ) $ (2.60 ) $ (10.91 ) $ (12.28 ) $ (28.70 ) Net income (loss) from discontinued operations (0.63 ) 0.32 (0.04 ) 1.66 1.30 Net income (loss) per share $ (3.54 ) $ (2.28 ) $ (10.95 ) $ (10.62 ) $ (27.40 ) 2014 Revenues and other $ 3,423 $ 3,323 $ 3,476 $ 2,858 $ 13,080 Gain (loss) on divestitures 3 (787 ) — (824 ) (1,608 ) Expenses (1) 2,786 2,839 3,817 8,342 17,784 Net income (loss) from continuing operations including noncontrolling interest 640 (303 ) (341 ) (6,308 ) (6,312 ) Net income (loss) from discontinued operations, net of tax (545 ) 68 (247 ) (983 ) (1,707 ) Net income (loss) including noncontrolling interest $ 95 $ (235 ) $ (588 ) $ (7,291 ) $ (8,019 ) Net income (loss) attributable to common stock $ (18 ) $ (354 ) $ (691 ) $ (7,297 ) $ (8,360 ) Basic net income (loss) per common share (2) : Net income (loss) from continuing operations $ 1.35 $ (1.10 ) $ (1.17 ) $ (16.77 ) $ (17.32 ) Net income (loss) from discontinued operations (1.38 ) 0.18 (0.65 ) (2.61 ) (4.44 ) Net income (loss) per share $ (0.03 ) $ (0.92 ) $ (1.82 ) $ (19.38 ) $ (21.76 ) Diluted net income (loss) per common share (2) : Net income (loss) from continuing operations $ 1.35 $ (1.10 ) $ (1.17 ) $ (16.77 ) $ (17.32 ) Net income (loss) from discontinued operations (1.38 ) 0.18 (0.65 ) (2.61 ) (4.44 ) Net income (loss) per share $ (0.03 ) $ (0.92 ) $ (1.82 ) $ (19.38 ) $ (21.76 ) (1) Continuing operating expenses for 2015 include non-cash asset impairments totaling $2.1 billion , $660 million , $4.1 billion , and $5.1 billion in the first, second, third, and fourth quarters of 2015, respectively. Continuing operating expenses for 2014 include non-cash asset impairments totaling $115 million , $162 million , $123 million , and $8.7 billion in the first, second, third, and fourth quarters of 2014, respectively. (2) The sum of the individual quarterly net income per common share amounts may not agree with full-year net income per common share as each quarterly computation is based on the weighted-average number of common shares outstanding during that period.

Supplemental Guarantor Inform44

Supplemental Guarantor Information (Tables)	12 Months Ended
	Dec. 31, 2015
Guarantees [Abstract]
Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income	CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME For the Year Ended December 31, 2015 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 1,446 $ — $ 5,064 $ — $ 6,510 Equity in net income (loss) of affiliates (5,254 ) (740 ) 57 5,937 — Other (71 ) 54 96 19 98 Gain (loss) on divestiture 36 — 245 — 281 (3,843 ) (686 ) 5,462 5,956 6,889 OPERATING EXPENSES: Lease operating expenses 399 — 1,455 — 1,854 Gathering and transportation 35 — 176 — 211 Taxes other than income 103 — 179 — 282 Exploration 2,096 — 675 — 2,771 General and administrative 296 — 65 19 380 Depreciation, depletion, and amortization 966 — 2,334 — 3,300 Asset retirement obligation accretion 15 — 130 — 145 Impairments 3,885 — 5,587 — 9,472 Transaction, reorganization, and separation 132 — — — 132 Financing costs, net 475 (14 ) 50 — 511 8,402 (14 ) 10,651 19 19,058 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES (12,245 ) (672 ) (5,189 ) 5,937 (12,169 ) Provision for income taxes (2,065 ) 11 1,044 — (1,010 ) NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (10,180 ) (683 ) (6,233 ) 5,937 (11,159 ) Net loss from discontinued operations, net of tax (172 ) — 664 — 492 NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST (10,352 ) (683 ) (5,569 ) 5,937 (10,667 ) Net income attributable to noncontrolling interest — — (315 ) — (315 ) NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (10,352 ) $ (683 ) $ (5,254 ) $ 5,937 $ (10,352 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (10,355 ) $ (683 ) $ (5,254 ) $ 5,937 $ (10,355 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME For the Year Ended December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 3,399 $ — $ 9,396 $ — $ 12,795 Equity in net income (loss) of affiliates (3,489 ) (1,191 ) 73 4,607 — Other 375 55 (150 ) 5 285 Gain (loss) on divestiture (1,031 ) — (577 ) — (1,608 ) (746 ) (1,136 ) 8,742 4,612 11,472 OPERATING EXPENSES: Lease operating expenses 509 — 1,729 — 2,238 Gathering and transportation 58 — 215 — 273 Taxes other than income 206 — 371 — 577 Exploration 1,966 — 533 — 2,499 General and administrative 370 — 78 5 453 Depreciation, depletion, and amortization 1,493 — 3,033 — 4,526 Asset retirement obligation accretion 31 — 123 — 154 Impairments 1,626 — 5,476 — 7,102 Transaction, reorganization, and separation 67 — — — 67 Financing costs, net 372 (24 ) 65 — 413 6,698 (24 ) 11,623 5 18,302 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES (7,444 ) (1,112 ) (2,881 ) 4,607 (6,830 ) Provision for income taxes 789 6 (1,313 ) — (518 ) NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST (8,233 ) (1,118 ) (1,568 ) 4,607 (6,312 ) Net income from discontinued operations, net of tax (127 ) — (1,580 ) — (1,707 ) NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST (8,360 ) (1,118 ) (3,148 ) 4,607 (8,019 ) Net income attributable to noncontrolling interest — — 341 — 341 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (8,360 ) $ (1,118 ) $ (3,489 ) $ 4,607 $ (8,360 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ (8,361 ) $ (1,118 ) $ (3,489 ) $ 4,607 $ (8,361 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME For the Year Ended December 31, 2013 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) REVENUES AND OTHER: Oil and gas production revenues $ 4,585 $ — $ 10,240 $ — $ 14,825 Equity in net income (loss) of affiliates 722 30 36 (788 ) — Other (399 ) 61 27 (4 ) (315 ) Gain (loss) on divestiture (670 ) — (561 ) — (1,231 ) 4,238 91 9,742 (792 ) 13,279 OPERATING EXPENSES: Lease operating expenses 939 — 1,711 — 2,650 Gathering and transportation 61 — 227 — 288 Taxes other than income 190 — 582 — 772 Exploration 332 — 610 — 942 General and administrative 411 — 84 (4 ) 491 Depreciation, depletion, and amortization 1,668 — 3,389 — 5,057 Asset retirement obligation accretion 67 — 144 — 211 Impairments 60 — 1,383 — 1,443 Transaction, reorganization, and separation 33 — — — 33 Financing costs, net 339 5 101 — 445 4,100 5 8,231 (4 ) 12,332 NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES 138 86 1,511 (788 ) 947 Provision (benefit) for income taxes (250 ) 20 1,171 — 941 NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST 388 66 340 (788 ) 6 Net income from discontinued operations, net of tax — — 438 — 438 NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST 388 66 778 (788 ) 444 Preferred stock dividends 44 — — — 44 Net income attributable to noncontrolling interest — — 56 — 56 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 344 $ 66 $ 722 $ (788 ) $ 344 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK $ 360 $ 66 $ 722 $ (788 ) $ 360
Supplemental Condensed Consolidating Statement of Cash Flows	CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS For the Year Ended December 31, 2015 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 98 $ 18 $ 2,438 $ — $ 2,554 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 113 — 113 CASH PROVIDED BY OPERATING ACTIVITIES 98 18 2,551 — 2,667 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (1,500 ) — (2,708 ) — (4,208 ) Additions to gas gathering, transmission, and processing facilities (156 ) — (77 ) — (233 ) Proceeds from sale of Kitimat LNG — — 854 — 854 Proceeds from sale of Yara Pilbara — — 391 — 391 Leasehold and property acquisitions (313 ) — (54 ) — (367 ) Proceeds from sale of oil and gas properties, other 163 — 105 — 268 Investment in subsidiaries, net 6,363 — — (6,363 ) — Other (34 ) — 40 — 6 NET CASH USED IN CONTINUING INVESTING ACTIVITIES 4,523 — (1,449 ) (6,363 ) (3,289 ) NET CASH PROVIDED BY DISCONTINUED OPERATIONS — — 4,372 — 4,372 NET CASH USED IN INVESTING ACTIVITIES 4,523 — 2,923 (6,363 ) 1,083 CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net (1,570 ) — — — (1,570 ) Intercompany borrowings (1,621 ) (18 ) (4,724 ) 6,363 — Payments on fixed rate debt (939 ) — — — (939 ) Dividends paid (377 ) — — — (377 ) Distributions to noncontrolling interest — — (129 ) — (129 ) Other (3 ) — 56 — 53 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (4,510 ) (18 ) (4,797 ) 6,363 (2,962 ) NET CASH USED IN FINANCING ACTIVITIES (4,510 ) (18 ) (4,797 ) 6,363 (2,962 ) NET INCREASE IN CASH AND CASH EQUIVALENTS 111 — 677 — 788 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 267 — 412 — 679 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 378 $ — $ 1,089 $ — $ 1,467 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS For the Year Ended December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 3,104 $ 17 $ 3,892 $ — $ 7,013 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 944 — 944 CASH PROVIDED BY OPERATING ACTIVITIES 3,104 17 4,836 — 7,957 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (4,364 ) — (4,244 ) — (8,608 ) Additions to gas gathering, transmission, and processing facilities (9 ) — (872 ) — (881 ) Proceeds from sale of Deepwater Gulf of Mexico assets 1,360 — — — 1,360 Proceeds from sale of Anadarko basin and southern Louisiana assets 1,262 — — — 1,262 Leasehold and property acquisitions (1,475 ) — — — (1,475 ) Proceeds from sale of oil and gas properties 15 — 455 — 470 Investment in subsidiaries, net 1,132 — — (1,132 ) — Other (186 ) — (113 ) — (299 ) NET CASH USED IN CONTINUING INVESTING ACTIVITIES (2,265 ) — (4,774 ) (1,132 ) (8,171 ) NET CASH PROVIDED BY DISCONTINUED OPERATIONS — — (219 ) — (219 ) NET CASH USED IN INVESTING ACTIVITIES (2,265 ) — (4,993 ) (1,132 ) (8,390 ) CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net 1,570 — (2 ) — 1,568 Intercompany borrowings — 8 (1,152 ) 1,144 — Dividends paid (365 ) — — — (365 ) Distributions to noncontrolling interest — — (140 ) — (140 ) Treasury stock activity, net (1,864 ) — — — (1,864 ) Other (68 ) (28 ) 157 (12 ) 49 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (727 ) (20 ) (1,137 ) 1,132 (752 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (42 ) — (42 ) NET CASH USED IN FINANCING ACTIVITIES (727 ) (20 ) (1,179 ) 1,132 (794 ) NET INCREASE (DECREAS) IN CASH AND CASH EQUIVALENTS 112 (3 ) (1,336 ) — (1,227 ) CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 155 3 1,748 — 1,906 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 267 $ — $ 412 $ — $ 679 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS For the Year Ended December 31, 2013 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES $ 1,076 $ 315 $ 6,873 $ — $ 8,264 CASH PROVIDED BY DISCONTINUED OPERATIONS — — 1,164 — 1,164 CASH PROVIDED BY OPERATING ACTIVITIES 1,076 315 8,037 — 9,428 CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas property (3,751 ) — (4,491 ) — (8,242 ) Additions to gas gathering, transmission, and processing facilities (124 ) — (340 ) — (464 ) Proceeds from divestiture of Gulf of Mexico Shelf properties 3,702 — — — 3,702 Leasehold and property acquisitions (195 ) — (234 ) — (429 ) Proceeds from Kitimat LNG transaction, net — 396 — 396 Proceeds from sale of oil and gas properties — — 307 — 307 Other (58 ) — (47 ) — (105 ) NET CASH USED IN CONTINUING INVESTING ACTIVITIES (426 ) — (4,409 ) — (4,835 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (1,874 ) — (1,874 ) NET CASH USED IN INVESTING ACTIVITIES (426 ) — (6,283 ) — (6,709 ) CASH FLOWS FROM FINANCING ACTIVITIES: Commercial paper, credit facility, and bank notes, net (501 ) — (8 ) — (509 ) Intercompany borrowings 3,056 1 (3,057 ) — — Payments on fixed rate debt (1,722 ) (350 ) — — (2,072 ) Dividends paid (360 ) — — — (360 ) Proceeds from sale of noncontrolling interest — — 2,948 — 2,948 Shares repurchased (997 ) — — — (997 ) Other 29 37 (45 ) — 21 NET CASH USED IN CONTINUING FINANCING ACTIVITIES (495 ) (312 ) (162 ) — (969 ) NET CASH USED IN DISCONTINUED OPERATIONS — — (4 ) — (4 ) NET CASH USED IN FINANCING ACTIVITIES (495 ) (312 ) (166 ) — (973 ) NET INCREASE IN CASH AND CASH EQUIVALENTS 155 3 1,588 — 1,746 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR — — 160 — 160 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 155 $ 3 $ 1,748 $ — $ 1,906
Supplemental Condensed Consolidating Balance Sheet	CONDENSED CONSOLIDATING BALANCE SHEET December 31, 2015 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) ASSETS CURRENT ASSETS: Cash and cash equivalents $ 378 $ — $ 1,089 $ — $ 1,467 Receivables, net of allowance 314 — 939 — 1,253 Inventories 34 — 536 — 570 Drilling advances 16 — 156 — 172 Prepaid assets and other 102 — 188 — 290 Intercompany receivable 5,212 — — (5,212 ) — 6,056 — 2,908 (5,212 ) 3,752 PROPERTY AND EQUIPMENT, NET 6,546 — 14,292 — 20,838 OTHER ASSETS: Intercompany receivable — — 10,744 (10,744 ) — Equity in affiliates 16,092 (807 ) 446 (15,731 ) — Deferred charges and other 96 1,001 813 (1,000 ) 910 $ 28,790 $ 194 $ 29,203 $ (32,687 ) $ 25,500 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable $ 409 $ — $ 209 $ — $ 618 Other current liabilities 539 3 681 — 1,223 Intercompany payable — — 5,212 (5,212 ) — 948 3 6,102 (5,212 ) 1,841 LONG-TERM DEBT 8,418 298 — — 8,716 DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES: Intercompany payable 10,744 — — (10,744 ) — Income taxes (412 ) 4 2,937 — 2,529 Asset retirement obligation 271 — 2,291 — 2,562 Other 933 250 179 (1,000 ) 362 11,536 254 5,407 (11,744 ) 5,453 COMMITMENTS AND CONTINGENCIES APACHE SHAREHOLDERS’ EQUITY 7,888 (361 ) 16,092 (15,731 ) 7,888 Noncontrolling interest — — 1,602 — 1,602 TOTAL EQUITY 7,888 (361 ) 17,694 (15,731 ) 9,490 $ 28,790 $ 194 $ 29,203 $ (32,687 ) $ 25,500 CONDENSED CONSOLIDATING BALANCE SHEET December 31, 2014 Apache Corporation Apache Finance Canada All Other Subsidiaries of Apache Corporation Reclassifications & Eliminations Consolidated (In millions) ASSETS CURRENT ASSETS: Cash and cash equivalents $ 267 $ — $ 412 $ — $ 679 Receivables, net of allowance 837 — 1,182 — 2,019 Inventories 24 — 657 — 681 Drilling advances 34 1 248 — 283 Assets held for sale — — 3,381 — 3,381 Deferred tax asset 612 — 278 — 890 Prepaid assets and other 32 — 97 — 129 Intercompany receivable 4,939 — — (4,939 ) — 6,745 1 6,255 (4,939 ) 8,062 PROPERTY AND EQUIPMENT, NET 12,146 — 22,499 — 34,645 OTHER ASSETS: Intercompany receivable 819 — 4,002 (4,821 ) — Equity in affiliates 21,346 (2 ) 324 (21,668 ) — Deferred charges and other 108 1,002 1,447 (1,000 ) 1,557 $ 41,164 $ 1,001 $ 34,527 $ (32,428 ) $ 44,264 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable $ 748 $ 10 $ 352 $ — $ 1,110 Liabilities held for sale — — 428 — 428 Other current liabilities 1,042 1 1,197 — 2,240 Intercompany payable — — 4,939 (4,939 ) — 1,790 11 6,916 (4,939 ) 3,778 LONG-TERM DEBT 10,880 298 — — 11,178 DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES: Intercompany payable 3,882 120 819 (4,821 ) — Income taxes 3,824 — 1,669 — 5,493 Asset retirement obligation 211 — 2,704 — 2,915 Other 2,082 250 (973 ) (1,000 ) 359 9,999 370 4,219 (5,821 ) 8,767 COMMITMENTS AND CONTINGENCIES APACHE SHAREHOLDERS’ EQUITY 18,495 322 21,346 (21,668 ) 18,495 Noncontrolling interest — — 2,046 — 2,046 TOTAL EQUITY 18,495 322 23,392 (21,668 ) 20,541 $ 41,164 $ 1,001 $ 34,527 $ (32,428 ) $ 44,264

Summary of Significant Accoun45

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments	$ 5,100,000,000	$ 4,100,000,000	$ 660,000,000	$ 2,100,000,000	$ 8,700,000,000	$ 123,000,000	$ 162,000,000	$ 115,000,000	$ 9,472,000,000	$ 7,102,000,000	$ 1,443,000,000
Asset impairments for property and equipment									11,600,000,000	8,000,000,000
Impairment of equity method investment									148,000,000
Inventory write-downs									55,000,000	32,000,000
Total asset impairment charges									11,942,000,000	9,080,000,000	1,800,000,000
Goodwill impairment charges									163,000,000	347,000,000	0
Impairment of assets held for sale and other assets										655,000,000
Cash and cash equivalents	1,467,000,000				679,000,000				1,467,000,000	679,000,000	1,906,000,000	$ 160,000,000
Allowance for doubtful accounts	103,000,000				98,000,000				103,000,000	98,000,000	78,000,000
Increase in allowance for doubtful accounts									5,000,000
Additional provisions on allowance for doubtful accounts									40,000,000
Allowance for doubtdul accounts written off									35,000,000
Capitalized internal costs	19,548,000,000				30,435,000,000				19,548,000,000	30,435,000,000
Gain (loss) recorded on divestitures									139,000,000
Oil and gas property, fair value	3,900,000,000				4,800,000,000				3,900,000,000	4,800,000,000	3,800,000,000
Gathering, transmission and processing facilities	1,052,000,000				5,440,000,000				1,052,000,000	5,440,000,000
Accumulated depreciation	25,312,000,000				26,813,000,000				25,312,000,000	26,813,000,000
Impairment of GTP assets									1,700,000,000
Fair value of GTP assets	306,000,000								306,000,000
Goodwill	87,000,000				250,000,000				87,000,000	250,000,000	737,000,000	1,289,000,000
Accounts payable									129,000,000	229,000,000
Net cost of third party gas									$ 105,000,000	70,000,000	39,000,000
Maximum percentage of production available to contract partners									40.00%
Other foreign currency gains and (losses)									$ 11,000,000	(8,000,000)	30,000,000
Benefit of tax deductions in excess of recognized compensation cost									1,000,000	(35,000)	(1,000,000)
GTP Facilities [Member]
Schedule Of Significant Accounting Policies [Line Items]
Gathering, transmission and processing facilities	1,100,000,000				5,400,000,000				1,100,000,000	5,400,000,000
Accumulated depreciation	160,000,000				1,700,000,000				160,000,000	1,700,000,000
Gain (loss) on the sale of GTP facilities									(59,000,000)	180,000,000
Oil and Gas Properties, Proved [Member]
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments for property and equipment									7,389,000,000	6,068,000,000	1,443,000,000
Other Property and Equipment [Member]
Schedule Of Significant Accounting Policies [Line Items]
Accumulated depreciation	693,000,000				673,000,000				693,000,000	673,000,000
United States [Member]
Schedule Of Significant Accounting Policies [Line Items]
Goodwill impairment charges									0	244,000,000	0
Capitalized internal costs	11,280,000,000				18,829,000,000				11,280,000,000	18,829,000,000
Impairment of GTP assets									103,000,000
Goodwill	0				0				0	0	384,000,000	1,016,000,000
Non-cash impairments of goodwill					1,100,000,000
Canada [Member]
Schedule Of Significant Accounting Policies [Line Items]
Goodwill impairment charges									0	103,000,000	0
Capitalized internal costs	2,026,000,000				3,531,000,000				2,026,000,000	3,531,000,000
Impairment of GTP assets									555,000,000
Goodwill	0				0				0	0	103,000,000	103,000,000
Egypt [Member]
Schedule Of Significant Accounting Policies [Line Items]
Goodwill impairment charges									0	0	0
Capitalized internal costs	3,264,000,000				3,496,000,000				3,264,000,000	3,496,000,000
Impairment of GTP assets									1,100,000,000
Goodwill	87,000,000				87,000,000				87,000,000	87,000,000	87,000,000	$ 87,000,000
Australia [Member]
Schedule Of Significant Accounting Policies [Line Items]
Capitalized internal costs					1,613,000,000					1,613,000,000
Australia [Member] | Discontinued Operations [Member]
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments										833,000,000
Australia [Member] | Oil and Gas Properties, Proved [Member] | Discontinued Operations [Member]
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments										271,000,000
Wheatstone LNG [Member] | Australia [Member]
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments					833,000,000
Apache Corporation [Member]
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments									3,885,000,000	1,626,000,000	60,000,000
Cash and cash equivalents	$ 378,000,000				$ 267,000,000				$ 378,000,000	$ 267,000,000	$ 155,000,000
Minimum [Member]
Schedule Of Significant Accounting Policies [Line Items]
Voting interest required for consolidation of investments	50.00%								50.00%
Minimum [Member] | Other Property and Equipment [Member]
Schedule Of Significant Accounting Policies [Line Items]
Useful lives of gas gathering, transmission and processing facilities									3 years
Maximum [Member]
Schedule Of Significant Accounting Policies [Line Items]
Voting interest required for consolidation of investments	50.00%								50.00%
Maximum [Member] | Other Property and Equipment [Member]
Schedule Of Significant Accounting Policies [Line Items]
Useful lives of gas gathering, transmission and processing facilities									20 years

Summary of Significant Accoun46

Summary of Significant Accounting Policies - Non-Cash Impairments of Proved and Unproved Property and Equipment (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Significant Accounting Policies [Line Items]
Impairment of Oil and Gas properties	$ 11,600	$ 8,000
Oil and Gas Properties, Proved [Member]
Schedule Of Significant Accounting Policies [Line Items]
Impairment of Oil and Gas properties	7,389	6,068	$ 1,443
Oil and Gas Properties, Unproved [Member]
Schedule Of Significant Accounting Policies [Line Items]
Impairment of Oil and Gas properties	$ 2,462	$ 1,976	$ 319

Summary of Significant Accoun47

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Schedule of Goodwill (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Roll Forward]
Goodwill, Beginning Balance	$ 250,000,000	$ 737,000,000	$ 1,289,000,000
Divested	0	(140,000,000)	(632,000,000)
Acquired			80,000,000
Impairments	(163,000,000)	(347,000,000)	0
Goodwill, Ending Balance	87,000,000	250,000,000	737,000,000
United States [Member]
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	384,000,000	1,016,000,000
Divested	0	(140,000,000)	(632,000,000)
Acquired			0
Impairments	0	(244,000,000)	0
Goodwill, Ending Balance	0	0	384,000,000
Canada [Member]
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	103,000,000	103,000,000
Divested	0	0	0
Acquired			0
Impairments	0	(103,000,000)	0
Goodwill, Ending Balance	0	0	103,000,000
Egypt [Member]
Goodwill [Roll Forward]
Goodwill, Beginning Balance	87,000,000	87,000,000	87,000,000
Divested	0	0	0
Acquired			0
Impairments	0	0	0
Goodwill, Ending Balance	87,000,000	87,000,000	87,000,000
North Sea [Member]
Goodwill [Roll Forward]
Goodwill, Beginning Balance	163,000,000	163,000,000	83,000,000
Divested	0	0	0
Acquired			80,000,000
Impairments	(163,000,000)	0	0
Goodwill, Ending Balance	$ 0	$ 163,000,000	$ 163,000,000

Change in Accounting Principl48

Change in Accounting Principle - Statement of Consolidated Operations (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									$ 6,510	$ 12,795	$ 14,825
Other revenue									98	285	(315)
Gain (loss) on divestiture	$ 77	$ (5)	$ 227	$ (18)	$ (824)	$ 0	$ (787)	$ 3	281	(1,608)	(1,231)
Exploration									2,771	2,499	942
General and administrative									380	453	491
Depreciation, depletion, and amortization									3,300	4,526	5,057
Impairments	5,100	4,100	660	2,100	8,700	123	162	115	9,472	7,102	1,443
Financing costs, net									511	413	445
Current income tax provision									435	1,281	1,673
Deferred income tax provision (benefit)									(1,445)	(1,799)	(732)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(5,055)	(4,119)	(917)	(1,068)	(6,308)	(341)	(303)	640	(11,159)	(6,312)	6
Net income (loss) attributable to noncontrolling interest									(315)	341	56
Net income (loss) from continuing operations attributable to common shareholders									(10,844)	(6,653)	(94)
Net income (loss) from discontinued operations, net of tax	627	(17)	120	(238)	(983)	(247)	68	(545)	492	(1,707)	438
Net income (loss) attributable to common shareholders	$ (4,015)	$ (4,143)	$ (860)	$ (1,334)	$ (7,297)	$ (691)	$ (354)	$ (18)	$ (10,352)	$ (8,360)	$ 344
Basic net income (loss) from continuing operations per share	$ (12.28)	$ (10.91)	$ (2.60)	$ (2.91)	$ (16.77)	$ (1.17)	$ (1.10)	$ 1.35	$ (28.70)	$ (17.32)	$ (0.24)
Basic net income (loss) from discontinued operations per share	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Basic net income (loss) per share	(10.62)	(10.95)	(2.28)	(3.54)	(19.38)	(1.82)	(0.92)	(0.03)	(27.40)	(21.76)	0.87
Diluted net income (loss) from continuing operations per share	(12.28)	(10.91)	(2.60)	(2.91)	(16.77)	(1.17)	(1.10)	1.35	(28.70)	(17.32)	(0.24)
Diluted net income (loss) from discontinued operations per share	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Diluted net income (loss) per share	$ (10.62)	$ (10.95)	$ (2.28)	$ (3.54)	$ (19.38)	$ (1.82)	$ (0.92)	$ (0.03)	$ (27.40)	$ (21.76)	$ 0.87
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax									$ (3)	$ 0	$ 9
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(10,355)	(8,361)	360
Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									6,510	12,795	14,825
Other revenue									98	285	(315)
Gain (loss) on divestiture									281	(1,608)	(1,231)
Exploration									2,771	2,499	942
General and administrative									380	453	491
Depreciation, depletion, and amortization									3,300	4,526	5,057
Impairments									9,472	7,102	1,443
Financing costs, net									511	413	445
Current income tax provision									435	1,281	1,673
Deferred income tax provision (benefit)									(1,445)	(1,799)	(732)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST									(11,159)	(6,312)	6
Net income (loss) attributable to noncontrolling interest									(315)	341
Net income (loss) from continuing operations attributable to common shareholders									(10,844)	(6,653)	(94)
Net income (loss) from discontinued operations, net of tax									492	(1,707)	438
Net income (loss) attributable to common shareholders									$ (10,352)	$ (8,360)	$ 344
Basic net income (loss) from continuing operations per share									$ (28.70)	$ (17.32)	$ (0.24)
Basic net income (loss) from discontinued operations per share									1.30	(4.44)	1.11
Basic net income (loss) per share									(27.40)	(21.76)	0.87
Diluted net income (loss) from continuing operations per share									(28.70)	(17.32)	(0.24)
Diluted net income (loss) from discontinued operations per share									1.30	(4.44)	1.11
Diluted net income (loss) per share									$ (27.40)	$ (21.76)	$ 0.87
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax									$ (3)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(10,355)	$ (8,361)	$ 360
Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									6,383	12,691	14,771
Other revenue									(76)	290	(333)
Gain (loss) on divestiture									59	(180)	0
Exploration									0	0	0
General and administrative									377	451	481
Depreciation, depletion, and amortization									29,372	9,720	5,866
Impairments									1,920	1,919	0
Financing costs, net									299	211	229
Current income tax provision									309	1,177	1,619
Deferred income tax provision (benefit)									(5,778)	(514)	309
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST									(22,757)	(3,472)	1,980
Net income (loss) attributable to noncontrolling interest									(409)	343
Net income (loss) from continuing operations attributable to common shareholders									(22,348)	(3,815)	1,880
Net income (loss) from discontinued operations, net of tax									(771)	(1,588)	308
Net income (loss) attributable to common shareholders									$ (23,119)	$ (5,403)	$ 2,188
Basic net income (loss) from continuing operations per share									$ (59.16)	$ (9.93)	$ 4.75
Basic net income (loss) from discontinued operations per share									(2.04)	(4.13)	0.78
Basic net income (loss) per share									(61.20)	(14.06)	5.53
Diluted net income (loss) from continuing operations per share									(59.16)	(9.93)	4.74
Diluted net income (loss) from discontinued operations per share									(2.04)	(4.13)	0.76
Diluted net income (loss) per share									$ (61.20)	$ (14.06)	$ 5.50
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax									$ 0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(23,119)	$ (5,404)	$ 2,204
Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									127	104	54
Other revenue									174	(5)	18
Gain (loss) on divestiture									222	(1,428)	(1,231)
Exploration									2,771	2,499	942
General and administrative									3	2	10
Depreciation, depletion, and amortization									(26,072)	(5,194)	(809)
Impairments									7,552	5,183	1,443
Financing costs, net									212	202	216
Current income tax provision									126	104	54
Deferred income tax provision (benefit)									4,333	(1,285)	(1,041)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST									11,598	(2,840)	(1,974)
Net income (loss) attributable to noncontrolling interest									94	(2)
Net income (loss) from continuing operations attributable to common shareholders									11,504	(2,838)	(1,974)
Net income (loss) from discontinued operations, net of tax									1,263	(119)	130
Net income (loss) attributable to common shareholders									$ 12,767	$ (2,957)	$ (1,844)
Basic net income (loss) from continuing operations per share									$ 30.46	$ (7.39)	$ (4.99)
Basic net income (loss) from discontinued operations per share									3.34	(0.31)	0.33
Basic net income (loss) per share									33.80	(7.70)	(4.66)
Diluted net income (loss) from continuing operations per share									30.46	(7.39)	(4.98)
Diluted net income (loss) from discontinued operations per share									3.34	(0.31)	0.35
Diluted net income (loss) per share									$ 33.80	$ (7.70)	$ (4.63)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax									$ (3)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									12,764	$ (2,957)	$ (1,844)
Oil [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									5,107	10,110	11,870
Oil [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									5,107	10,110	11,870
Oil [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									4,999	10,040	11,853
Oil [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									108	70	17
Natural Gas [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									1,176	2,017	2,303
Natural Gas [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									1,176	2,017	2,303
Natural Gas [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									1,157	1,983	2,266
Natural Gas [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									19	34	37
Natural Gas Liquids [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									227	668	652
Natural Gas Liquids [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									227	668	652
Natural Gas Liquids [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									227	668	652
Natural Gas Liquids [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Oil and gas production revenues									0	0	0
Recurring [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									2,976	4,195	4,705
Recurring [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									3,531	4,388	4,534
Recurring [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									(555)	(193)	171
Additional [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									0	0	0
Additional [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									25,517	5,001	995
Additional [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									(25,517)	(5,001)	(995)
Other assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization									$ 324	$ 331	352
Other assets [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization											352
Other assets [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization											337
Other assets [Member] | Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation, depletion, and amortization											$ 15

Change in Accounting Principl49

Change in Accounting Principle - Statement of Consolidated Cash Flow (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	$ (4,428)	$ (4,136)	$ (797)	$ (1,306)	$ (7,291)	$ (588)	$ (235)	$ 95	$ (10,667)	$ (8,019)	$ 444
Loss (income) from discontinued operations									(492)	1,707	(438)
Gain (Loss) on Disposition of Business	(77)	5	(227)	18	824	0	787	(3)	(281)	1,608	1,231
Exploratory dry hole expense and unproved leasehold impairments									2,595	2,294	729
Depreciation, depletion, and amortization									3,300	4,526	5,057
Impairments	5,100	$ 4,100	$ 660	2,100	8,700	$ 123	$ 162	115	9,472	7,102	1,443
Other									7	(231)	300
Deferred income tax provision (benefit)									(1,445)	(1,799)	(732)
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES									2,554	7,013	8,264
CASH PROVIDED BY DISCONTINUED OPERATIONS									113	944	1,164
Additions to oil and gas property									(4,208)	(8,608)	(8,242)
Net cash provided by (used in) investing activities - continuing operations									(3,289)	(8,171)	(4,835)
NET CASH PROVIDED BY (USED IN) DISCONTINUED OPERATIONS									4,372	(219)	(1,874)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS									788	(1,227)	1,746
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR				679				1,906	679	1,906	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	1,467				679				1,467	679	1,906
Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									(10,667)	(8,019)	444
Loss (income) from discontinued operations									(492)	1,707	(438)
Gain (Loss) on Disposition of Business									(281)	1,608	1,231
Exploratory dry hole expense and unproved leasehold impairments									2,595	2,294	729
Depreciation, depletion, and amortization									3,300	4,526	5,057
Impairments									9,472	7,102	1,443
Other									7
Deferred income tax provision (benefit)									(1,445)	(1,799)	(732)
Changes in operating assets and liabilities									(80)	(329)
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES									2,554	7,013	8,264
CASH PROVIDED BY DISCONTINUED OPERATIONS									113	944	1,164
Additions to oil and gas property									(4,208)	(8,608)	(8,242)
Net cash provided by (used in) investing activities - continuing operations									(3,289)	(8,171)	(4,835)
NET CASH PROVIDED BY (USED IN) DISCONTINUED OPERATIONS									4,372	(219)	(1,874)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS									788	(1,227)	1,746
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR				679				1,906	679	1,906	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	1,467				679				1,467	679	1,906
Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									(23,528)	(5,060)	2,288
Loss (income) from discontinued operations									771	1,588	(308)
Gain (Loss) on Disposition of Business									(59)	180	0
Exploratory dry hole expense and unproved leasehold impairments									0	0	0
Depreciation, depletion, and amortization									29,372	9,720	5,866
Impairments									1,920	1,919	0
Other									161
Deferred income tax provision (benefit)									(5,778)	(514)	309
Changes in operating assets and liabilities									(170)	(239)
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES									2,834	7,517	8,685
CASH PROVIDED BY DISCONTINUED OPERATIONS									150	944	1,150
Additions to oil and gas property									(4,578)	(9,022)	(8,663)
Net cash provided by (used in) investing activities - continuing operations									(3,659)	(8,585)	(5,256)
NET CASH PROVIDED BY (USED IN) DISCONTINUED OPERATIONS									4,335	(219)	(1,860)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS									698	(1,137)	1,746
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR				769				1,906	769	1,906	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	1,467				769				1,467	769	1,906
Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									12,861	(2,959)	(1,844)
Loss (income) from discontinued operations									(1,263)	119	(130)
Gain (Loss) on Disposition of Business									(222)	1,428	1,231
Exploratory dry hole expense and unproved leasehold impairments									2,595	2,294	729
Depreciation, depletion, and amortization									(26,072)	(5,194)	(809)
Impairments									7,552	5,183	1,443
Other									(154)
Deferred income tax provision (benefit)									4,333	(1,285)	(1,041)
Changes in operating assets and liabilities									90	(90)
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES									(280)	(504)	(421)
CASH PROVIDED BY DISCONTINUED OPERATIONS									(37)	0	14
Additions to oil and gas property									370	414	421
Net cash provided by (used in) investing activities - continuing operations									370	414	421
NET CASH PROVIDED BY (USED IN) DISCONTINUED OPERATIONS									37	0	(14)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS									90	(90)	0
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR				$ (90)				$ 0	(90)	0	0
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$ 0				$ (90)				$ 0	$ (90)	$ 0

Change in Accounting Principl50

Change in Accounting Principle - Consolidated Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	$ 1,467	$ 679	$ 1,906	$ 160
Receivables, net of allowance	1,253	2,019
Inventories	570	681
Drilling advances	172	283
Assets held for sale		3,381
Deferred tax asset		890
Property and equipment - cost	46,150	61,458
Less: Accumulated depreciation, depletion, and amortization	(25,312)	(26,813)
Property and equipment, net	20,838	34,645
Deferred charges and other	910	1,557
Total assets	25,500	44,264
Accounts payable	618	1,110
Liabilities held for sale		428
Other current liabilities	1,223	2,240
Asset retirement obligation, long-term	2,562	2,915
Deferred income taxes	2,529	5,493
Paid-in capital	12,619	12,590
Retained earnings (accumulated deficit)	(1,980)	8,655
Accumulated other comprehensive loss	(119)	(116)	(115)
Noncontrolling interest	1,602	2,046
TOTAL EQUITY	9,490	20,541	30,756	28,538
Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
TOTAL EQUITY				31,331
Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect of change on equity				2,793
Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	1,467	679	1,906	160
Receivables, net of allowance		2,019
Inventories		681
Drilling advances		283
Assets held for sale		3,381
Deferred tax asset		890
Property and equipment - cost	46,150	61,458
Less: Accumulated depreciation, depletion, and amortization	(25,312)	(26,813)
Property and equipment, net	20,838	34,645
Deferred charges and other		1,557
Total assets	25,500	44,264
Accounts payable		1,110
Liabilities held for sale		428
Other current liabilities		2,240
Asset retirement obligation, long-term		2,915
Deferred income taxes	2,529	5,493
Paid-in capital	12,619	12,590
Retained earnings (accumulated deficit)	(1,980)	8,655
Accumulated other comprehensive loss	(119)
Noncontrolling interest	1,602	2,046
TOTAL EQUITY	9,490	20,541
Change from Full Cost Method to Successful Efforts Method [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	1,467	769	1,906	160
Receivables, net of allowance		2,024
Inventories		708
Drilling advances		388
Assets held for sale		1,628
Deferred tax asset		769
Property and equipment - cost	93,825	103,458
Less: Accumulated depreciation, depletion, and amortization	(79,706)	(55,382)
Property and equipment, net	14,119	48,076
Deferred charges and other		1,394
Total assets	18,781	55,885
Accounts payable		1,210
Liabilities held for sale		19
Other current liabilities		2,435
Asset retirement obligation, long-term		3,048
Deferred income taxes	1,072	9,499
Paid-in capital	12,467	12,438
Retained earnings (accumulated deficit)	(7,153)	16,249
Accumulated other comprehensive loss	(116)
Noncontrolling interest	1,662	2,200
TOTAL EQUITY	4,228	28,137
Change from Full Cost Method to Successful Efforts Method [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	0	(90)	0	0
Receivables, net of allowance		(5)
Inventories		(27)
Drilling advances		(105)
Assets held for sale		1,753
Deferred tax asset		121
Property and equipment - cost	(47,675)	(42,000)
Less: Accumulated depreciation, depletion, and amortization	54,394	28,569
Property and equipment, net	6,719	(13,431)
Deferred charges and other		163
Total assets	6,719	(11,621)
Accounts payable		(100)
Liabilities held for sale		409
Other current liabilities		(195)
Asset retirement obligation, long-term		(133)
Deferred income taxes	1,457	(4,006)
Paid-in capital	152	152
Retained earnings (accumulated deficit)	5,173	(7,594)
Accumulated other comprehensive loss	(3)
Noncontrolling interest	(60)	(154)
TOTAL EQUITY	5,262	(7,596)
Retained Earnings (Accumulated Deficit) [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
TOTAL EQUITY	$ (1,980)	$ 8,655	$ 17,395	17,368
Retained Earnings (Accumulated Deficit) [Member] | Under Full Cost [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
TOTAL EQUITY				20,161
Retained Earnings (Accumulated Deficit) [Member] | Changes [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect of change on equity				2,793
Retained Earnings (Accumulated Deficit) [Member] | Change from Full Cost Method to Successful Efforts Method [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect of change on equity				$ 2,800

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information - 2015 Activity - Yara Pilbara Holdings Pty Limited Sale (Detail) - USD ($) $ in Millions	Oct. 28, 2015	Sep. 30, 2015	Dec. 31, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceed from sale of equity method investments			$ 391
Yara Pilbara Holdings Pty Limited [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of ownership	49.00%
Proceed from sale of equity method investments	$ 391
Impairment on equity method investment		$ 148

Acquisitions and Divestitures52

Acquisitions and Divestitures - Additional Information - 2015 Activity - Canada Divestiture (Detail) - USD ($) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Apr. 30, 2015

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 854

Asset impairments

$ 5,100

$ 4,100

$ 660

$ 2,100

$ 8,700

$ 123

$ 162

$ 115

9,472

$ 7,102

$ 1,443

Loss on sale of upstream assets

$ 139

Canada [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 854

Kitimat LNG [Member] | Canada [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Percentage of ownership

50.00%

Proceeds form sale of operations

$ 344

Asset impairments

$ 655

Upstream Assets [Member] | Canada [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

510

Loss on sale of upstream assets

$ 146

Acquisitions and Divestitures53

Acquisitions and Divestitures - Additional Information - 2015 Activity - Australia Divestiture (Detail) - USD ($) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jun. 30, 2015

Apr. 30, 2015

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 268

$ 96

$ 307

Asset impairments

$ 5,100

$ 4,100

$ 660

$ 2,100

$ 8,700

$ 123

$ 162

$ 115

9,472

$ 7,102

$ 1,443

Loss on sale of upstream assets

(139)

Wheatstone LNG [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairments

$ 833

Wheatstone LNG [Member] | Oil and Gas Properties [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Loss on sale of upstream assets

$ (49)

Woodside Sale [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 2,800

Consortium Sale [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 1,900

LNG Assets [Member] | Woodside Sale [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

1,400

Upstream Assets [Member] | Woodside Sale [Member] | Australia [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds form sale of operations

$ 1,400

Acquisitions and Divestitures54

Acquisitions and Divestitures - Summary of Carrying Amount of Major Assets and Liabilities Associated with Disposition - Australia Divestitures (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
ASSETS
Current assets held for sale	$ 3,752	$ 8,062
Oil and gas assets, net	19,548	30,435
Total assets	25,500	44,264
LIABILITIES
Current liabilities held for sale	1,841	3,778
Other current liabilities	1,223	2,240
Asset retirement obligations	2,562	2,915
Non-current deferred tax liability	2,529	5,493
Other long-term liabilities	$ 362	359
Australia [Member]
ASSETS
Oil and gas assets, net		1,613
Divestiture [Member] | Australia [Member]
ASSETS
Current assets held for sale		3,019
Other current assets		590
Oil and gas assets, net		1,613
GTP and other assets, net		877
Total assets		6,099
LIABILITIES
Current liabilities held for sale		321
Other current liabilities		318
Asset retirement obligations		466
Non-current deferred tax liability		329
Other long-term liabilities		33
Total liabilities		$ 1,467

Acquisitions and Divestitures55

Acquisitions and Divestitures - Summary of Sales and Other Operating Revenue and Loss From Discontinued Operation Related to Disposition - Australia Divestitures (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended								12 Months Ended
	Jun. 30, 2015	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of tax		$ 627	$ (17)	$ 120	$ (238)	$ (983)	$ (247)	$ 68	$ (545)	$ 492	$ (1,707)	$ 438
Australia [Member] | Divestiture [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues and other from discontinued operations										288	1,050	1,121
Income (loss) from divested Australian operations										28	(12)	550
Income tax benefit (expense)										(652)	231	22
Income (loss) from discontinued operations, net of tax										492	(1,076)	$ 528
Australia [Member] | Divestiture [Member] | Woodside Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss from divestiture										$ (49)	$ (833)
Australia [Member] | Divestiture [Member] | Consortium Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss from divestiture	$ (139)

Acquisitions and Divestitures56

Acquisitions and Divestitures - Additional Information - 2014 Activity - Anadarko Basin and Southern Louisiana Divestitures (Detail)	1 Months Ended	12 Months Ended
	Dec. 31, 2014USD ($)a	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)a	Dec. 31, 2013USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets		$ 268,000,000	$ 470,000,000	$ 307,000,000
Goodwill impairment charges		$ 163,000,000	$ 347,000,000	$ 0
Anadarko Basin and Southern Louisiana [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets	$ 1,300,000,000
Anadarko Basin [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Oil and gas properties sold | a	115,000		115,000
Loss on sale of oil and gas property	$ 823,000,000
Goodwill impairment charges	10,000,000
Loss on disposal of assets, before tax	$ 180,000,000
Southern Louisiana [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Oil and gas properties sold | a	90,000		90,000

Acquisitions and Divestitures57

Acquisitions and Divestitures - Additional Information - 2014 Activity - Gulf of Mexico Deepwater Divestiture (Detail) - USD ($)	Jun. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale of 11 primary-term deepwater exploration blocks		$ 268,000,000	$ 470,000,000	$ 307,000,000
Goodwill impairment charges		$ 163,000,000	$ 347,000,000	$ 0
Deepwater Gulf of Mexico [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale of 11 primary-term deepwater exploration blocks	$ 1,400,000,000
Effective date of sale	May 1, 2014
Loss on sale of oil and gas property	$ 332,000,000
Goodwill impairment charges	$ 130,000,000

Acquisitions and Divestitures58

Acquisitions and Divestitures - Additional Information - 2014 Activity - Canada Divestiture (Detail) $ in Millions	Apr. 30, 2014USD ($)a	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets		$ 268	$ 470	$ 307
Natural Gas [Member] | Canada [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets	$ 374
Oil and gas properties sold | a	328,400
Effective date of sale	Jan. 1, 2014
Loss on sale of oil and gas property	$ 237
Natural Gas Liquids [Member] | Canada [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Working interest percentage in Wapiti area	100.00%

Acquisitions and Divestitures59

Acquisitions and Divestitures - Additional Information - 2014 Activity - Argentina Divestiture (Detail) - USD ($) $ in Millions	Mar. 12, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets		$ 268	$ 470	$ 307
Argentina [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets	$ 800
Liabilities assumed	$ 52
Debt assumed beginning date	Jun. 30, 2013

Acquisitions and Divestitures60

Acquisitions and Divestitures - Summary of Sales and Other Operating Revenue and Loss From Discontinued Operation Related to Disposition (Detail) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss from divestiture									$ (139)
Income (loss) from discontinued operations, net of tax	$ 627	$ (17)	$ 120	$ (238)	$ (983)	$ (247)	$ 68	$ (545)	$ 492	$ (1,707)	$ 438
Argentina [Member] | Divestiture [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues and other from discontinued operations										87	494
Loss from divestiture										(654)
Income (loss) from operations in Argentina										(1)	(90)
Income tax benefit (expense)										23
Income (loss) from discontinued operations, net of tax										$ (632)	$ (90)

Acquisitions and Divestitures61

Acquisitions and Divestitures - Additional Information - 2013 Activity - Egypt Partnership (Detail) - USD ($) $ in Millions	Nov. 14, 2013	Dec. 31, 2015	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds as noncontrolling interest		$ 1,602	$ 2,046
Egypt Oil and Gas [Member] | Sinopec [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of operations	$ 2,950
Proceeds as noncontrolling interest	$ 1,800

Acquisitions and Divestitures62

Acquisitions and Divestitures - Additional Information - 2013 Activity - Gulf of Mexico Shelf Divestiture (Detail) - USD ($)	Sep. 30, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Goodwill impairment charges		$ 163,000,000	$ 347,000,000	$ 0
Fieldwood Energy LLC [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of operations	$ 3,700,000,000
Liabilities assumed	$ 1,500,000,000
Percentage of ownership interest in assets	50.00%
Effective date of the transaction		Jul. 1, 2013
Loss on sale of oil and gas property	$ 1,600,000,000
Goodwill impairment charges	$ 632,000,000

Acquisitions and Divestitures63

Acquisitions and Divestitures - Additional Information - 2013 Activity - Canada LNG Project (Detail)	Feb. 28, 2013USD ($)a	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas assets		$ 268,000,000	$ 470,000,000	$ 307,000,000
Chevron Canada and Apache Canada [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from limited partnership	$ 398,000,000
Kitimat LNG [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of ownership	50.00%
Proceeds from transaction	$ 396,000,000
Proceeds from sale of oil and gas assets	$ 644,000,000
Kitimat LNG [Member] | Horn River and Liard Basins [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business properties held | a	644,000

Acquisitions and Divestitures64

Acquisitions and Divestitures - Additional Information - 2013 Activity (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Business Combinations [Abstract]
Leasehold and property acquisition	$ 367	$ 1,475	$ 429
Transaction, reorganization, and separation expense	132	67	33
Proceeds form sale of operations	268	96	307
Gain (loss) on disposition of assets	$ 135	$ (216)	$ (3)

Capitalized Exploratory Well 65

Capitalized Exploratory Well Costs - Capitalized Exploratory Well Costs Rollforward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Capitalized exploratory well costs, Beginning Balance	$ 849	$ 630	$ 546
Additions pending determination of proved reserves	382	622	549
Divestitures and other	(557)	(54)	(136)
Reclassifications to proved properties	(369)	(207)	(244)
Charged to exploration expense	(60)	(142)	(85)
Capitalized exploratory well costs, Ending Balance	$ 245	849	$ 630
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Assets held for sale		3,381
Australia [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Assets held for sale		$ 49

Capitalized Exploratory Well 66

Capitalized Exploratory Well Costs - Aging of Suspended Well Balances (Details) $ in Millions	Dec. 31, 2015USD ($)Project	Dec. 31, 2014USD ($)Project	Dec. 31, 2013USD ($)Project	Dec. 31, 2012USD ($)
Extractive Industries [Abstract]
Exploratory well costs capitalized for a period of one year or less	$ 184	$ 504	$ 350
Exploratory well costs capitalized for a period greater than one year	61	345	280
Capitalized exploratory well costs	$ 245	$ 849	$ 630	$ 546
Number of projects with exploratory well costs capitalized for a period greater than one year | Project	2,000,000	18,000,000	30,000,000

Capitalized Exploratory Well 67

Capitalized Exploratory Well Costs - Aging by Geographic Area of Exploratory Well Costs Capitalized Greater than One Year (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	$ 61	$ 345	$ 280
2014 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	3
2013 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
2012 and Prior [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	58
North Sea [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	61
North Sea [Member] | 2014 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	3
North Sea [Member] | 2013 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
North Sea [Member] | 2012 and Prior [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Exploratory well costs capitalized for a period greater than one year	$ 58

Derivative Instruments and He68

Derivative Instruments and Hedging Activities - Commodity Derivative Activity Recorded in Statement of Consolidated Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Loss on cash flow hedges reclassified from accumulated other comprehensive loss		$ (16)
Loss for ineffectiveness on cash flow hedges		(1)
Gain (loss) on derivatives not designated as cash flow hedges	$ 284	(399)
Derivatives Not Designated as Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized loss	(16)	(178)
Unrealized gain (loss)	$ 300	$ (221)

Other Current Liabilities - Det

Other Current Liabilities - Details of Other Current Liabilities (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Payables and Accruals [Abstract]
Accrued operating expenses	$ 139	$ 154
Accrued exploration and development	637	1,425
Accrued compensation and benefits	166	204
Accrued interest	144	160
Accrued income taxes	47	54
Current asset retirement obligation	36	37
Current debt	1
Other	53	206
Total Other current liabilities	$ 1,223	$ 2,240

Asset Retirement Obligation - A

Asset Retirement Obligation - Asset Retirement Obligation (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligation at beginning of year	$ 2,952	$ 3,222
Liabilities incurred	68	171
Liabilities divested	(490)	(471)
Liabilities settled	(90)	(146)
Accretion expense	158	181
Revisions in estimated liabilities		128
Liabilities held for sale	0	(133)
Asset retirement obligation at end of year	2,598	2,952
Less current portion	(36)	(37)
Asset retirement obligation, long-term	$ 2,562	$ 2,915

Asset Retirement Obligation -71

Asset Retirement Obligation - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation [Line Items]
Asset retirement obligation accretion	$ 145	$ 154	$ 211
Additional abandonment liabilities associated with its drilling and development program	68	171
Net Income (Loss) From Discontinued Operations, Net Of Tax [Member]
Asset Retirement Obligation [Line Items]
Asset retirement obligation accretion	$ 13	$ 27

Debt - Additional Information (

Debt - Additional Information (Detail) € in Millions	Feb. 25, 2016EUR (€)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)Contract	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Debt Instrument [Line Items]
Debt before unamortized discount				$ 8,831,000,000
Payments of notes				939,000,000		$ 2,072,000,000
Line of credit facility, amount terminated			$ 5,300,000,000
Commercial paper program				3,500,000,000
Carrying Amount, Commercial paper					$ 1,600,000,000
Unamortized discount				53,000,000
Amortization of Debt Discount (Premium)					3,000,000
Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt before unamortized discount				8,831,000,000	11,301,000,000
Unamortized discount				53,000,000	$ 56,000,000
Apache finance Canada 7.75% notes due 2029 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount				300,000,000
5.625% Notes Due 2017 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount		$ 500,000,000
Notes interest rate		5.625%
Payments of notes		$ 939,000,000
Accrued and unpaid interest		8,000,000
5.625% Notes Due 2017 [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt maturity year					2,017
1.75% Notes Due 2017 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount		$ 400,000,000
Notes interest rate		1.75%
Jp Morgan Chase Bank And Syndicate Of Lenders [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Letter of credit facility | €	€ 900
Credit facility, extension period for maturity	1 year
Line of credit facility maximum borrowing capacity | €	€ 1,075
Five-Year Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility term			5 years
Credit facility maturity date			Jun. 30, 2020
Line of credit facility, number of extension options | Contract			2
Credit facility, extension period for maturity			1 year
Line of credit facility maximum borrowing capacity			$ 3,500,000,000
Line of credit facility, available borrowing capacity				$ 3,500,000,000
Quarterly facility fees at per annum rate				0.125%
Maximum potential lien on assets located in specified regions				$ 1,275,000,000
Five-Year Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment amount			4,500,000,000
Debt to Capitalization ratio				0.60
Percentage of liens of companies consolidated asset				5.00%
Five-Year Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Margin percentage				1.00%
Notes Payable, Other Payables [Member]
Debt Instrument [Line Items]
Period For Borrowing Funds				270 days
Letter of Credit [Member]
Debt Instrument [Line Items]
Letter of credit subfacility			$ 750,000,000

Debt - Debt for Apache and Subs

Debt - Debt for Apache and Subsidiaries (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Debt before unamortized discount	$ 8,831
Unamortized discount	(53)
Debt issuance costs	(61)	$ (67)
Total debt	8,717	11,178
Current maturities	(1)
Long-term debt	8,716	11,178
Commercial Paper [Member]
Debt Instrument [Line Items]
Total debt		1,570
Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	8,831	11,301
Unamortized discount	(53)	(56)
Total debt	8,717	11,178
Current maturities	(1)
Long-term debt	8,716	11,178
Unsecured Debt [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Debt before unamortized discount		1,570
Unsecured Debt [Member] | United States [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	8,530	11,000
Unsecured Debt [Member] | 5.625% notes due 2017 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount		500
Unsecured Debt [Member] | 1.75% Notes Due 2017 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount		400
Unsecured Debt [Member] | 6.9% notes due 2018 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	400	400
Unsecured Debt [Member] | 7.0% notes due 2018 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	150	150
Unsecured Debt [Member] | 7.625% notes due 2019 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	150	150
Unsecured Debt [Member] | 3.625% notes due 2021 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	500	500
Unsecured Debt [Member] | 3.25% notes due 2022 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	919	919
Unsecured Debt [Member] | 2.625% notes due 2023 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	531	531
Unsecured Debt [Member] | 7.7% notes due 2026 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	100	100
Unsecured Debt [Member] | 7.95% notes due 2026 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	180	180
Unsecured Debt [Member] | 6.0% notes due 2037 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	1,000	1,000
Unsecured Debt [Member] | 5.1% notes due 2040 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	1,500	1,500
Unsecured Debt [Member] | 5.25% notes due 2042 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	500	500
Unsecured Debt [Member] | 4.75% notes due 2043 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	1,500	1,500
Unsecured Debt [Member] | 4.25% notes due 2044 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	800	800
Unsecured Debt [Member] | 7.375% debentures due 2047 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	150	150
Unsecured Debt [Member] | 7.625% debentures due 2096 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	150	150
Unsecured Debt [Member] | Notes due In 2016 and 2017 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	1	1
Unsecured Debt [Member] | Apache finance Canada 7.75% notes due 2029 [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	300	300
Unsecured Debt [Member] | Subsidiary And Other Obligations [Member]
Debt Instrument [Line Items]
Debt before unamortized discount	$ 301	$ 301

Debt - Debt for Apache and Su74

Debt - Debt for Apache and Subsidiaries (Parenthetical) (Detail) - Unsecured Debt [Member]	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
5.625% notes due 2017 [Member]
Debt Instrument [Line Items]
Notes interest rate	5.625%	5.625%
Debt maturity year	2,017	2,017
1.75% Notes Due 2017 [Member]
Debt Instrument [Line Items]
Notes interest rate	1.75%	1.75%
Debt maturity year	2,017	2,017
6.9% notes due 2018 [Member]
Debt Instrument [Line Items]
Notes interest rate	6.90%	6.90%
Debt maturity year	2,018	2,018
7.0% notes due 2018 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.00%	7.00%
Debt maturity year	2,018	2,018
7.625% notes due 2019 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.625%	7.625%
Debt maturity year	2,019	2,019
3.625% notes due 2021 [Member]
Debt Instrument [Line Items]
Notes interest rate	3.625%	3.625%
Debt maturity year	2,021	2,021
3.25% notes due 2022 [Member]
Debt Instrument [Line Items]
Notes interest rate	3.25%	3.25%
Debt maturity year	2,022	2,022
2.625% notes due 2023 [Member]
Debt Instrument [Line Items]
Notes interest rate	2.625%	2.625%
Debt maturity year	2,023	2,023
7.7% notes due 2026 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.70%	7.70%
Debt maturity year	2,026	2,026
7.95% notes due 2026 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.95%	7.95%
Debt maturity year	2,026	2,026
6.0% notes due 2037 [Member]
Debt Instrument [Line Items]
Notes interest rate	6.00%	6.00%
Debt maturity year	2,037	2,037
5.1% notes due 2040 [Member]
Debt Instrument [Line Items]
Notes interest rate	5.10%	5.10%
Debt maturity year	2,040	2,040
5.25% notes due 2042 [Member]
Debt Instrument [Line Items]
Notes interest rate	5.25%	5.25%
Debt maturity year	2,042	2,042
4.75% notes due 2043 [Member]
Debt Instrument [Line Items]
Notes interest rate	4.75%	4.75%
Debt maturity year	2,043	2,043
4.25% notes due 2044 [Member]
Debt Instrument [Line Items]
Notes interest rate	4.25%	4.25%
Debt maturity year	2,044	2,044
7.375% debentures due 2047 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.375%	7.375%
Debt maturity year	2,047	2,047
7.625% debentures due 2096 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.625%	7.625%
Debt maturity year	2,096	2,096
Notes due In 2016 and 2017 [Member]
Debt Instrument [Line Items]
Debt maturity year	2,016	2,017
Apache finance Canada 7.75% notes due 2029 [Member]
Debt Instrument [Line Items]
Notes interest rate	7.75%	7.75%
Debt maturity year	2,029	2,029

Debt - Schedule of Long Term De

Debt - Schedule of Long Term Debt by Maturity (Detail) $ in Millions	Dec. 31, 2015USD ($)
Debt Disclosure [Abstract]
2016 and 2017	$ 1
2,018	550
2,019	150
Thereafter	8,130
Total Debt, excluding discounts	$ 8,831

Debt - Summary of Carrying Amou

Debt - Summary of Carrying Amounts and Estimated Fair Values (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Debt, Carrying Value	$ 8,717	$ 11,178
Debt, Fair Value	8,330	11,514
Commercial Paper [Member]
Debt Instrument [Line Items]
Debt, Carrying Value		1,570
Debt, Fair Value		1,570
Notes and Debentures [Member]
Debt Instrument [Line Items]
Debt, Carrying Value	8,717	9,608
Debt, Fair Value	8,330	9,944
Deferred charges and other [Member] | Accounting Standards Update 2015-03 [Member]
Debt Instrument [Line Items]
Debt issuance costs	$ (61)	$ (67)

Debt - Components of Financing

Debt - Components of Financing Costs, Net (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Disclosure [Abstract]
Interest expense	$ 486	$ 499	$ 560
Amortization of deferred loan costs	11	6	8
Interest Costs Capitalized Adjustment	(15)	(85)	(99)
Loss (gain) on extinguishment of debt	39		(16)
Interest income	(10)	(7)	(8)
Financing costs, net	$ 511	$ 413	$ 445

Income Taxes - Income (Loss) Be

Income Taxes - Income (Loss) Before Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
U.S.	$ (9,386)	$ (4,807)	$ (1,166)
Foreign	(2,783)	(2,023)	2,113
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	$ (12,169)	$ (6,830)	$ 947

Income Taxes - Total Provision

Income Taxes - Total Provision for Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current taxes:
Federal	$ 363	$ (10)	$ (29)
State	41	1
Foreign	31	1,290	1,702
Current tax, net	435	1,281	1,673
Deferred taxes:
Federal	(1,123)	(671)	(83)
State	(51)	(45)	17
Foreign	(271)	(1,083)	(666)
Deferred taxes, net	(1,445)	(1,799)	(732)
Total	$ (1,010)	$ (518)	$ 941

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Tax of Income Before Income Taxes and Total Tax Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Income tax expense (benefit) at U.S. statutory rate	$ (4,259)	$ (2,391)	$ 331
State income tax, less federal benefit	(7)	(28)	12
Taxes related to foreign operations	(662)	(147)	89
Tax credits	(6)		6
Tax on distributed foreign earnings	726	311	225
Foreign tax credit carryforwards	(2,090)
Deferred tax on undistributed foreign earnings	1,903	560
Tax impact of goodwill adjustments	82	161	221
Change in U.K. tax rate	(414)
Net change in tax contingencies	20	(3)	(10)
Valuation allowances	3,746	1,021	125
All other, net	(49)	(2)	(58)
Total	$ (1,010)	$ (518)	$ 941

Income Taxes - Net Deferred Tax

Income Taxes - Net Deferred Tax Liability (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Deferred tax assets:
Deferred income	$ 20
U.S. and state net operating loss carryforwards	329	$ 1,333
Foreign net operating loss carryforwards	1,507	366
Tax credits and other tax incentives	82	42
Foreign tax credit carryforwards	2,090
Accrued expenses and liabilities	136	68
Asset retirement obligation	1,037	1,202
Property and equipment	1,529	856
Total deferred tax assets	6,730	3,867
Valuation allowance	(5,434)	(1,564)	$ (598)	$ (375)
Net deferred tax assets	1,296	2,303
Deferred tax liabilities:
Other	4	19
Deferred income	140	24
Investment in foreign subsidiaries	1,903	1,119
Property and equipment	1,773	5,755
Total deferred tax liabilities	3,820	6,917
Net deferred income tax liability	$ 2,524	$ 4,614

Income Taxes - Net Deferred T82

Income Taxes - Net Deferred Tax Assets and Liabilities (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Assets:
Deferred tax asset		$ (890)
Deferred charges and other	$ (5)	(17)
Liabilities
Other current liabilities		28
Deferred income taxes	2,529	5,493
Net deferred income tax liability	$ 2,524	$ 4,614

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax [Line Items]
Current income tax liability	$ 560
Deferred income tax liability on undistributed foreign earnings		$ 560
Deferred income tax expense on foreign undistributed earnings		311	$ 225
Non-cash ceiling test write-downs due to change in deferred tax position	19
Foreign tax credit carryforward, amount	2,090
Tax expense (benefit) recorded		1	1
Accrued for payment of interest and penalties	1	0	1
Reserve for uncertain tax positions related to the current year	19
Settlements	3
Increase in valuation allowances	3,900	966	$ 223
United States [Member]
Income Tax [Line Items]
Deferred income tax liability on undistributed foreign earnings		$ 560
Tax expense (benefit) recorded	$ 1
United Kingdom [Member]
Income Tax [Line Items]
Supplementary charge percentage	20.00%	32.00%
Deferred tax benefit related to change in enacted legislation	$ 414
United States [Member]
Income Tax [Line Items]
Operating loss carryforwards	198
Canada [Member]
Income Tax [Line Items]
Operating loss carryforwards	60
Capital loss carryforwards	$ 848

Income Taxes - Summary of Valua

Income Taxes - Summary of Valuation Allowance Against Certain Foreign Net Deferred Tax Assets and State Net Operating Losses (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Balance at beginning of year	$ 1,564	$ 598	$ 375
State	151	62	30
U.S.	2,159
Foreign	(1,560)	(1,021)	(125)
Discontinued operations		(117)	68
Balance at end of year	$ 5,434	$ 1,564	$ 598

Income Taxes - Net Operating Lo

Income Taxes - Net Operating Losses (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
United States [Member]
Net operating losses:
Net operating losses	$ 198
State [Member]
Net operating losses:
Net operating losses, Expiration	Various
Net operating losses	$ 3,496
Canada [Member]
Net operating losses:
Net operating losses	$ 60
Minimum [Member] | United States [Member]
Net operating losses:
Net operating losses, Expiration	2,018
Minimum [Member] | Canada [Member]
Net operating losses:
Net operating losses, Expiration	2,028
Maximum [Member] | United States [Member]
Net operating losses:
Net operating losses, Expiration	2,035
Maximum [Member] | Canada [Member]
Net operating losses:
Net operating losses, Expiration	2,035

Income Taxes - Schedule of Fore

Income Taxes - Schedule of Foreign Tax Credit Carryforward (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Tax Credit Carryforward [Line Items]
Foreign tax credits	$ 2,090
Minimum [Member]
Tax Credit Carryforward [Line Items]
Foreign tax credits, year of expiration	2,025
Maximum [Member]
Tax Credit Carryforward [Line Items]
Foreign tax credits, year of expiration	2,026

Income Taxes - Reconciliation87

Income Taxes - Reconciliation of Beginning and Ending Amount of Unrecognized Tax Benefits (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Balance	$ 19	$ 0	$ 3
Additions based on tax positions related to the current year	19
Reductions for tax positions of prior years		(3)
Balance	$ 19	$ 0	$ 3

Income Taxes - Key Jurisdiction

Income Taxes - Key Jurisdictions of Company's Earliest Open Tax Years (Detail)	12 Months Ended
	Dec. 31, 2015
United States [Member]
Schedule Of Income Tax [Line Items]
Open Tax Years by Major Tax Jurisdiction	2,011
Canada [Member]
Schedule Of Income Tax [Line Items]
Open Tax Years by Major Tax Jurisdiction	2,011
Egypt [Member]
Schedule Of Income Tax [Line Items]
Open Tax Years by Major Tax Jurisdiction	1,998
United Kingdom [Member]
Schedule Of Income Tax [Line Items]
Open Tax Years by Major Tax Jurisdiction	2,013

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2015CAD	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Sep. 30, 2015USD ($)	Mar. 12, 2014USD ($)	Jan. 31, 2012	Jan. 30, 2012
Commitment And Contingencies [Line Items]
Accrued liability for legal contingencies	$ 29,000,000
Environmental tax and royalty obligations						$ 100,000,000
Retain right of obligations	$ 67,500,000
Loss contingency estimate of possible loss					$ 237,000
Percentage of combined ownership held by the plaintiff in the company	65.00%	65.00%
Maximum cost considered to be recognized for additional reserve	$ 300,000
Undiscounted reserve for environmental remediation	52,000,000
Administrative penalty | CAD		CAD 16,500
Net rental expenses	$ 57,000,000		$ 45,000,000	$ 40,000,000
Lease expiration	2,035	2,035
Contractual obligation cost incurred	$ 92,000,000		$ 89,000,000	$ 72,000,000
Apollo Exploration Lawsuit [Member]
Commitment And Contingencies [Line Items]
Loss contingency damages sought value	1,100,000,000
Working Capital Adjustments [Member] | Wheatstone Lng And Kitimat Lng [Member]
Commitment And Contingencies [Line Items]
Purchase price adjustments amount	175,000,000
Other Adjustment [Member] | Wheatstone Lng And Kitimat Lng [Member]
Commitment And Contingencies [Line Items]
Purchase price adjustments amount	$ 214,000,000
Minimum [Member]
Commitment And Contingencies [Line Items]
Percentage of acquisition	50.00%
Loss contingency receivable	$ 833,000,000
Minimum [Member] | Cameron Parish School Board [Member]
Commitment And Contingencies [Line Items]
Loss contingency damages sought value	$ 7,000,000
Maximum [Member]
Commitment And Contingencies [Line Items]
Percentage of acquisition	50.00%
Loss contingency receivable	$ 2,274,000,000
Maximum [Member] | Cameron Parish School Board [Member]
Commitment And Contingencies [Line Items]
Loss contingency damages sought value	96,000,000
Oswal [Member]
Commitment And Contingencies [Line Items]
Expected contractual general damages	$ 491,000,000
Burrup Holdings Limited (Yara Pilbara Holdings Pty Limited ) [Member]
Commitment And Contingencies [Line Items]
Percentage of acquisition							49.00%
Yara International [Member]
Commitment And Contingencies [Line Items]
Percentage of acquisition							51.00%	35.00%

Commitments and Contingencies90

Commitments and Contingencies - Contractual Obligations (Detail) $ in Millions	Dec. 31, 2015USD ($)
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	$ 1,528
2,016	383
2017-2018	573
2019-2020	300
2021 & Beyond	272
Office Equipment [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	342
2,016	43
2017-2018	87
2019-2020	72
2021 & Beyond	140
Drilling Rig Commitments [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	405
2,016	194
2017-2018	211
Purchase Obligations [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	354
2,016	28
2017-2018	115
2019-2020	139
2021 & Beyond	72
Firm Transportation Agreements [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	363
2,016	96
2017-2018	125
2019-2020	83
2021 & Beyond	59
Other Contractual Obligation [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Total	64
2,016	22
2017-2018	35
2019-2020	6
2021 & Beyond	$ 1

Retirement and Deferred Compe91

Retirement and Deferred Compensation Plans - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitment And Contingencies [Line Items]
Maximum percentage of compensation contributed by the company	8.00%
Portion of employee's salary, employee contributions under non-qualified retirement savings plan	50.00%
Maximum percentage of eligible compensation contributed by the participating employees	50.00%
Percentage of additional contribution to money purchase retirement plan	6.00%
Portion of employee's annual bonus, employee contributions under non-qualified retirement savings plan, vested	75.00%
Portion occurring as money purchase retirement plan and the non-qualified retirement/savings plan, vested	20.00%
Annual cost of retirement benefit plans	$ 77	$ 107	$ 123
Targeted ongoing funding level of pension plan policy, percent	100.00%
Outperformance relative to gilts for equities	3.50%
Pension Benefits [Member]
Commitment And Contingencies [Line Items]
Accumulated benefit obligation for pension plans	$ 169	$ 183	$ 160
Expected contribution towards pension and postretirement plan	7
Postretirement Benefits [Member]
Commitment And Contingencies [Line Items]
Expected contribution towards pension and postretirement plan	$ 2

Retirement and Deferred Compe92

Retirement and Deferred Compensation Plans - Changes in Benefit Obligation, Fair Value of Plan Assets and Funded Status of Pension and Postretirement Benefit Plans (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Change in Projected Benefit Obligation
Benefits paid			$ (4)
Change in Plan Assets
Fair value of plan assets at beginning of year	$ 206
Benefits paid			(4)
Fair value of plan assets at end of year	197	$ 206
Pension Benefits [Member]
Change in Projected Benefit Obligation
Projected benefit obligation beginning of year	216	189	177
Service cost	5	5	5
Interest cost	8	9	7
Foreign currency exchange rate changes	(10)	(13)	4
Actuarial losses (gains)	(10)	31
Benefits paid	(7)	(5)	(4)
Projected benefit obligation at end of year	202	216	189
Change in Plan Assets
Fair value of plan assets at beginning of year	206	191	170
Actual return on plan assets	1	25	15
Foreign currency exchange rates	(10)	(13)	4
Employer contributions	7	8	6
Benefits paid	(7)	(5)	(4)
Fair value of plan assets at end of year	197	206	191
Defined Benefit Plan, Net Periodic Benefit Cost	(7)	(4)	(6)
Funded status at end of year	(5)	(10)	2
Amounts recognized in Consolidated Balance Sheet
Current liability			0
Non-current asset (liability)	(5)	(10)	2
Defined Benefit Plans, Liabilities, Total	(5)	(10)	2
Pre-tax Amounts Recognized in Accumulated Other Comprehensive Income (Loss)
Accumulated gain (loss)	$ (32)	$ (37)	$ (22)
Weighted Average Assumptions used as of December 31
Discount rate	3.90%	3.70%	4.60%
Salary increases	4.60%	4.60%	4.90%
Expected return on assets	4.10%	3.90%	5.60%
Postretirement Benefits [Member]
Change in Projected Benefit Obligation
Projected benefit obligation beginning of year	$ 22	$ 28	$ 35
Service cost	2	3	4
Interest cost	1	1	1
Actuarial losses (gains)		(9)	(8)
Effect of curtailment and settlements	2		(3)
Benefits paid	(2)	(2)	(2)
Retiree contributions	(1)	(1)	(1)
Projected benefit obligation at end of year	26	22	28
Change in Plan Assets
Employer contributions	1	1	1
Benefits paid	(2)	(2)	(2)
Retiree contributions	(1)	(1)	(1)
Defined Benefit Plan, Net Periodic Benefit Cost	(3)	(4)	(2)
Funded status at end of year	(26)	(22)	(28)
Amounts recognized in Consolidated Balance Sheet
Current liability	(2)	(1)	(1)
Non-current asset (liability)	(24)	(21)	(27)
Defined Benefit Plans, Liabilities, Total	(26)	(22)	(28)
Pre-tax Amounts Recognized in Accumulated Other Comprehensive Income (Loss)
Accumulated gain (loss)	$ 9	$ 10	$ 1
Weighted Average Assumptions used as of December 31
Discount rate	3.95%	3.62%	4.33%
Healthcare cost trend
Initial	7.00%	7.00%	7.00%
Ultimate in 2025	5.00%	5.00%	5.00%

Retirement and Deferred Compe93

Retirement and Deferred Compensation Plans - Allocations for Plan Asset Holding and Target Allocation for Company's Plan Asset (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	100.00%
Percentage of Plan Assets at Year-End	100.00%	100.00%
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	40.00%
Percentage of Plan Assets at Year-End	40.00%	40.00%
Equity Securities [Member] | UK Quoted Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	14.00%
Percentage of Plan Assets at Year-End	14.00%	14.00%
Equity Securities [Member] | Overseas Quoted Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	26.00%
Percentage of Plan Assets at Year-End	26.00%	26.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	60.00%
Percentage of Plan Assets at Year-End	60.00%	60.00%
Debt Securities [Member] | U.K. Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	48.00%
Percentage of Plan Assets at Year-End	48.00%	48.00%
Debt Securities [Member] | U.K. Corporate Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	12.00%
Percentage of Plan Assets at Year-End	12.00%	12.00%

Retirement and Deferred Compe94

Retirement and Deferred Compensation Plans - Fair Values of Plan Assets for Each Major Asset Category Based on Nature and Significant Concentration of Risks in Plan Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 197	$ 206
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	80	82
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	117	124
Quoted Price in Active Markets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	197	206
Quoted Price in Active Markets (Level 1) [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	80	82
Quoted Price in Active Markets (Level 1) [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	117	124
UK Quoted Equities [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	28
UK Quoted Equities [Member] | Quoted Price in Active Markets (Level 1) [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	28
Overseas Quoted Equities [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	53	54
Overseas Quoted Equities [Member] | Quoted Price in Active Markets (Level 1) [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	53	54
U.K. Government Bonds [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	93	99
U.K. Government Bonds [Member] | Quoted Price in Active Markets (Level 1) [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	93	99
U.K. Corporate Bonds [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	24	25
U.K. Corporate Bonds [Member] | Quoted Price in Active Markets (Level 1) [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 24	$ 25

Retirement and Deferred Compe95

Retirement and Deferred Compensation Plans - Fair Values of Plan Assets for Each Major Asset Category Based on Nature and Significant Concentration of Risks in Plan Assets (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities	100.00%	100.00%
U.K. Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Period for the portion of UK Equities, overseas equities, government bonds and corporate bonds, benchmarked against FTSE	5 years
Overseas Quoted Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Performance target over the benchmark	2.00%
Period for the portion of UK Equities, overseas equities, government bonds and corporate bonds, benchmarked against FTSE	3 years
U.K. Corporate Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Benchmarked against BofAML Sterling Corporate & Collateralised (excluding Subordinated) Index	12.00%
Performance target over the benchmark	0.75%
Index - Linked Index [Member] | U.K. Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of debt securities government bonds and corporate bonds benchmarked against FTSE	48.00%
FTSE Actuaries Government Securities Index [Member] | U.K. Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Period for the portion of UK Equities, overseas equities, government bonds and corporate bonds, benchmarked against FTSE	5 years
Sterling Nominal LDI Bonds [Member] | Nominal LDI Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Benchmarked against ILIM Custom Benchmark index	37.00%
Sterling Inflation Linked LDI Bonds [Member] | Inflation Linked LDI Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Benchmarked against ILIM Custom Benchmark index	15.00%
Passive Global Equities [Member] | MSCI World Index [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities		30.30%
Passive Global Equities Hedged [Member] | MSCI World Index [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities		12.10%
Fundamental Indexation Global Equities [Member] | FTSE RAFI Developed 1000 Index [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities		30.30%
Fundamental Indexation Global Equities Hedged [Member] | FTSE RAFI Developed 1000 Index [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities		12.10%
Emerging Markets [Member] | MSCI World Index [Member]
Defined Benefit Plan Disclosure [Line Items]
Portion of overseas equities		15.20%

Retirement and Deferred Compe96

Retirement and Deferred Compensation Plans - Components of Net Periodic Cost and Underlying Weighted Average Actuarial Assumptions Used for Pension and Postretirement Benefit Plans (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits [Member]
Component of Net Periodic Benefit Costs
Service cost	$ 5	$ 5	$ 5
Interest cost	8	9	7
Expected return on assets	(8)	(11)	(8)
Amortization of actuarial (gain) loss	2	1	2
Net periodic benefit cost	$ 7	$ 4	$ 6
Weighted Average Assumptions used to determine Net Period Benefit Cost for the Years ended December 31
Discount rate	3.70%	4.60%	4.30%
Salary increases	4.60%	4.90%	4.60%
Expected return on assets	3.90%	5.60%	4.70%
Postretirement Benefits [Member]
Component of Net Periodic Benefit Costs
Service cost	$ 2	$ 3	$ 4
Interest cost	1	1	1
Curtailment (gain) loss			(3)
Net periodic benefit cost	$ 3	$ 4	$ 2
Weighted Average Assumptions used to determine Net Period Benefit Cost for the Years ended December 31
Discount rate	3.62%	4.33%	3.43%
Healthcare cost trend
Initial	7.00%	7.00%	7.25%
Ultimate in 2025	5.00%	5.00%	5.00%

Retirement and Deferred Compe97

Retirement and Deferred Compensation Plans - Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates (Detail) - Postretirement Benefits [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Effect on service and interest cost components, 1% Increase	$ (1)
Effect on postretirement benefit obligation, 1% Increase	(4)
Effect on service and interest cost components, 1% Decrease	(1)
Effect on postretirement benefit obligation, 1% Decrease	$ (3)

Retirement and Deferred Compe98

Retirement and Deferred Compensation Plans - Expected Future Benefit Payment (Detail) $ in Millions	Dec. 31, 2015USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2,016	$ 4
2,017	4
2,018	4
2,019	4
2,020	4
Years 2021-2025	22
Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2,016	2
2,017	2
2,018	2
2,019	2
2,020	2
Years 2021-2025	$ 10

Capital Stock - Common Stock Ou

Capital Stock - Common Stock Outstanding (Detail) - shares	Jun. 10, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Equity [Abstract]
Balance, beginning of year		376,504,892	395,772,908	391,640,770
Shares issued for stock-based compensation plans:
Treasury shares issued		17,525	17,454	25,214
Common shares issued		1,511,758	1,665,259	929,596
Common shares issued for conversion of preferred shares				14,399,247
Treasury shares acquired	(32,200,000)		(20,950,729)	(11,221,919)
Balance, end of year		378,034,175	376,504,892	395,772,908

Capital Stock - Net Income Per

Capital Stock - Net Income Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share [Abstract]
Income (loss) from continuing operations, basic									$ (10,844)	$ (6,653)	$ (94)
Income (loss) from discontinued operations									492	(1,707)	438
Net income (loss) attributable to common shareholders	$ (4,015)	$ (4,143)	$ (860)	$ (1,334)	$ (7,297)	$ (691)	$ (354)	$ (18)	(10,352)	(8,360)	344
Income (loss) from continuing operations, diluted									(10,844)	(6,653)	(94)
Income (loss) from discontinued operations									492	(1,707)	438
Net income (loss) attributable to common stock									$ (10,352)	$ (8,360)	$ 344
Income (loss) from continuing operations, shares									378	384	395
Income (loss) from discontinued operations, shares									378	384	395
Income (loss) attributable to common stock, shares									378	384	395
Income (loss) from continuing operations, shares									378	384	395
Income (loss) from discontinued operations, shares									378	384	395
Income (loss) attributable to common stock, shares									378	384	395
Basic income (loss) from continuing operations per share	$ (12.28)	$ (10.91)	$ (2.60)	$ (2.91)	$ (16.77)	$ (1.17)	$ (1.10)	$ 1.35	$ (28.70)	$ (17.32)	$ (0.24)
Basic income (loss) from discontinued operations per share	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Net income (loss) attributable to common stock, per share	(10.62)	(10.95)	(2.28)	(3.54)	(19.38)	(1.82)	(0.92)	(0.03)	(27.40)	(21.76)	0.87
Diluted income (loss) from continuing operations per share	(12.28)	(10.91)	(2.60)	(2.91)	(16.77)	(1.17)	(1.10)	1.35	(28.70)	(17.32)	(0.24)
Diluted income (loss) from discontinued operations per share	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Net income (loss) attributable to common stock, per share	$ (10.62)	$ (10.95)	$ (2.28)	$ (3.54)	$ (19.38)	$ (1.82)	$ (0.92)	$ (0.03)	$ (27.40)	$ (21.76)	$ 0.87

Capital Stock - Additional Info

Capital Stock - Additional Information (Detail) - USD ($)	Jun. 10, 2013	Feb. 29, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options and restricted stock, anti-dilutive			7,000,000	4,500,000	6,800,000
Common stock share purchase, shares			40,000,000
Common stock share repurchase, shares	32,200,000			20,950,729	11,221,919
Common stock share repurchase, per share	$ 88.96
Dividends, Common stock			$ 1	$ 0.95	$ 0.77
Shares authorized and available for grant under 2011 Plan			18,000,000
Compensation expense			$ 100,000,000	$ 148,000,000	$ 136,000,000
Stock-based compensation expenses, after tax			65,000,000	95,000,000	94,000,000
Intrinsic value of options exercised			3,000,000	13,000,000	4,000,000
Cash received from exercise of options			16,000,000
Additional tax benefit for the amount of intrinsic value in excess of compensation cost			$ 973,767
Granted, Weighted Average Grant-Date Fair Value			$ 61.65
Restricted stock, capitalized			$ 53,000,000	62,000,000	55,000,000
Unvested restricted stock units			4,570,203
Percentage of additional vest on succeeding anniversaries			25.00%
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 90,000,000	93,000,000	82,000,000
Stock-based compensation expenses, after tax			58,000,000	$ 60,000,000	$ 53,000,000
Total compensation cost related to non-vested options not yet recognized			$ 217,000,000
Compensation expense			2,976,000	3,046,744	3,098,029
Granted, Weighted Average Grant-Date Fair Value			$ 61.65	$ 86.87	$ 82.95
Restricted stock, capitalized			$ 48,000,000	$ 43,000,000	$ 30,000,000
Weighted-average remaining life of unvested restricted stock units			1 year 1 month 6 days
Total fair value of restricted stock awards vested			$ 149,000,000	$ 138,000,000	$ 88,000,000
Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		2,881,924
Subsequent Event [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		119,000,000
Granted, Weighted Average Grant-Date Fair Value		$ 41.24
Non Employee Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock units, vested (Percentage)			50.00%
Equity Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period in which stock options expires after grant date			10 years
Total compensation cost related to non-vested options not yet recognized			$ 5,000,000
Equity Option [Member] | Scenario, Forecast [Member] | 2011 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 9,000,000
Period in which stock options become exercisable		3 years
Options Issued		872,574

Capital Stock - Description of

Capital Stock - Description of Stock Based Compensation Plans and Related Costs (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Stock-based compensation expensed:
Allocated Share-based Compensation Expense	$ 100	$ 148	$ 136
Restricted stock, capitalized	53	62	55
Total	153	210	191
General and Administrative Expense [Member]
Stock-based compensation expensed:
Allocated Share-based Compensation Expense	64	107	89
Lease Operating Expenses [Member]
Stock-based compensation expensed:
Allocated Share-based Compensation Expense	$ 36	$ 41	$ 47

Capital Stock - Summary of Stoc

Capital Stock - Summary of Stock Options Issued Under Stock Option Plans (Detail) shares in Thousands	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Equity [Abstract]
Outstanding, beginning of year, Shares | shares	6,445
Granted, Shares | shares	0
Exercised, Shares | shares	(280)
Forfeited or expired, Shares | shares	(1,234)
Outstanding, end of year, Shares | shares	4,931
Expected to vest, Shares | shares	566
Exercisable, end of year, Shares | shares	4,311
Outstanding, beginning of year, Weighted Average exercise Price | $ / shares	$ 90.34
Granted, Weighted Average Exercise Price | $ / shares	0
Exercised, Weighted Average Exercise Price | $ / shares	56.72
Forfeited or expired, Weighted Average Exercise Price | $ / shares	93.28
Outstanding, end of year, Weighted Average Exercise Price | $ / shares	91.52
Expected to vest, Weighted Average Exercise Price | $ / shares	81.77
Exercisable, end of year, Weighted Average Exercise Price | $ / shares	$ 92.92

Capital Stock - Summary of S104

Capital Stock - Summary of Stock Options Issued Under Stock Option Plans (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Weighted average remaining contractual life for options outstanding	4 years 6 months
Weighted average remaining contractual life for expected to vest	6 years 10 months 24 days
Weighted average remaining contractual life for exercisable	4 years 1 month 6 days

Capital Stock - Restricted Stoc

Capital Stock - Restricted Stock (Detail) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested at January 1, 2014, Weighted Average Grant Date Fair Value	$ 81.96
Granted, Weighted Average Grant-Date Fair Value	61.65
Vested, Weighted Average Grant-Date Fair Value	81.14
Forfeited, Weighted Average Grant-Date Fair Value	78.26
Non-vested at December 31, 2014, Weighted Average Grant Date Fair Value	$ 70.12	$ 81.96
Business Performance Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, Shares	602,000
Forfeited or expired, Shares	(101,000)
Restricted Shares, nonvested, Ending Balance, Shares	501,000
Granted, Weighted Average Grant-Date Fair Value	$ 66.63
Forfeited or expired, Weighted Average Grant-Date Fair Value	66.63
Non-vested at December 31, 2014, Weighted Average Grant Date Fair Value	$ 66.63
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted Shares, nonvested, Beginning Balance, Shares	4,784,000
Granted, Shares	2,976,000	3,046,744	3,098,029
Vested, Shares	(1,839,000)
Forfeited or cancelled, Shares	(1,351,000)
Restricted Shares, nonvested, Ending Balance, Shares	4,570,000	4,784,000
Granted, Weighted Average Grant-Date Fair Value	$ 61.65	$ 86.87	$ 82.95

Capital Stock - Additional I106

Capital Stock - Additional Information 1 (Detail) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended				12 Months Ended
	Jan. 31, 2016	Feb. 28, 2015	Jan. 31, 2014	Jan. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	May 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities, shares					7,000,000	4,500,000	6,800,000
Percentage of additional vest on succeeding anniversaries					25.00%
Compensation expense					$ 100,000	$ 148,000	$ 136,000
Stock-based compensation expenses, after tax					65,000	95,000	94,000
Restricted stock, capitalized					$ 53,000	$ 62,000	55,000
Unvested restricted stock units					4,570,203
Weighted average grant date fair value per share					$ 61.65
Total Shareholder Return Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested shares outstanding					172,000	354,000
Compensation expense					$ 648	$ 18,000	27,000
Stock-based compensation expenses, after tax					418	11,000	17,000
Restricted stock, capitalized					0	$ 7,000	$ 13,000
Total compensation cost related to non-vested options not yet recognized					$ 4,700
Unvested restricted stock units					172,212
Weighted-average remaining life of unvested restricted stock units					1 year 9 months 18 days
Weighted average grant date fair value per share					$ 0
Conditional Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested shares outstanding					500,972
Compensation expense					$ 3,400
Stock-based compensation expenses, after tax					2,200
Restricted stock, capitalized					1,400
Total compensation cost related to non-vested options not yet recognized					$ 29,000
Weighted-average remaining life of unvested restricted stock units					2 years 4 months 24 days
2013 Total Shareholder Return Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Initial conditional restricted stock unit awards granted to eligible employees				1,232,176
Nonvested shares outstanding								918,016
Minimum units awarded based upon measurement					0
Maximum units awarded based upon measurement					216,434
Total awards, outstanding					108,217
2014 Total Shareholder Return Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Initial conditional restricted stock unit awards granted to eligible employees			157,406
Minimum units awarded based upon measurement					0
Maximum units awarded based upon measurement					127,990
Total awards, outstanding					63,995
Performance Program 2015 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Initial conditional restricted stock unit awards granted to eligible employees		602,304
Minimum units awarded based upon measurement					0
Maximum units awarded based upon measurement					751,458
Total awards, outstanding					500,972
Performance Program 2016 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Minimum units awarded based upon measurement					0
Maximum units awarded based upon measurement					1,710,526
Weighted average grant date fair value per share					$ 36.55
Performance Program 2016 [Member] | Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Initial conditional restricted stock unit awards granted to eligible employees	855,263
Total Shareholder Return Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares allocation percentage					50.00%
Business Performance Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested shares outstanding					501,000
Percentage of shares awarded					150.00%
Weighted average grant date fair value per share					$ 66.63
Business Performance Program [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares vesting percentage					50.00%
Remaining shares vesting percentage					50.00%
Shares vesting period					3 years
Business Performance Program [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of shares awarded					0.00%
Share-based Compensation Award, Tranche One [Member] | Business Performance Program [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares vesting percentage					50.00%
Mandatory Convertible Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities, shares							8,300,000

Capital Stock - Conditional Res

Capital Stock - Conditional Restricted Stock (Detail) shares in Thousands	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested at January 1, 2014, Weighted Average Grant Date Fair Value	$ 81.96
Granted, Weighted Average Grant-Date Fair Value	61.65
Vested, Weighted Average Grant-Date Fair Value	81.14
Non-vested at December 31, 2014, Weighted Average Grant Date Fair Value	$ 70.12
Total Shareholder Return Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted Shares, nonvested, Beginning Balance, Shares | shares	354
Granted, Shares | shares	0
Vested, Shares | shares	0
Forfeited or expired, Shares | shares	(182)
Restricted Shares, nonvested, Ending Balance, Shares | shares	172
Non-vested at January 1, 2014, Weighted Average Grant Date Fair Value	$ 78.13
Granted, Weighted Average Grant-Date Fair Value	0
Vested, Weighted Average Grant-Date Fair Value	0
Forfeited or expired, Weighted Average Grant-Date Fair Value	72.09
Non-vested at December 31, 2014, Weighted Average Grant Date Fair Value	$ 78.22

Accumulated Other Comprehens108

Accumulated Other Comprehensive Loss - Components of Accumulated Other Comprehensive Income (Loss) (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
Currency translation adjustment	$ (109)	$ (109)	$ (109)
Unrealized gain (loss) on derivatives	0	0	1
Unfunded pension and postretirement benefit plan	(10)	(7)	(7)
Accumulated other comprehensive loss	$ (119)	$ (116)	$ (115)

Major Customers - Additional In

Major Customers - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Customer Concentration Risk [Member] | Oil and Gas Production Revenues [Member] | Shell Plc [Member]
Revenue, Major Customer [Line Items]
Entity wide revenue major customer percentage	11.00%	19.00%	24.00%

Business Segment Information -

Business Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015Country
Segment Reporting [Abstract]
Production in number of countries	4

Business Segment Information111

Business Segment Information - Financial Segment Information (Detail) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Oil and gas production revenues									$ 6,510	$ 12,795	$ 14,825
Depreciation, depletion, and amortization									3,300	4,526	5,057
Exploration									2,771	2,499	942
Asset retirement obligation accretion									145	154	211
Lease operating expenses									1,854	2,238	2,650
Gathering and transportation									211	273	288
Taxes other than income									282	577	772
Impairments									9,472	7,102	1,443
Operating Income (Loss)									(11,525)	(4,574)	3,462
Other Income (Expense):
Gain (loss) on divestiture	$ 77	$ (5)	$ 227	$ (18)	$ (824)	$ 0	$ (787)	$ 3	281	(1,608)	(1,231)
Other									98	285	(315)
General and administrative									(380)	(453)	(491)
Transaction, reorganization, and separation									(132)	(67)	(33)
Financing costs, net									(511)	(413)	(445)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									(12,169)	(6,830)	947
Net property and equipment	20,838				32,154				20,838	32,154	39,713
Total Assets	25,500				38,165				25,500	38,165	47,261
Additions to Net Property and Equipment	4,106				10,725				4,106	10,725	9,529
United States [Member]
Segment Reporting Information [Line Items]
Oil and gas production revenues									2,637	5,744	6,902
Depreciation, depletion, and amortization									1,558	2,408	2,690
Exploration									2,145	2,113	629
Asset retirement obligation accretion									28	43	94
Lease operating expenses									739	921	1,320
Gathering and transportation									68	93	84
Taxes other than income									184	350	335
Impairments									6,266	2,622	96
Operating Income (Loss)									(8,351)	(2,806)	1,654
Other Income (Expense):
Net property and equipment	11,753				19,507				11,753	19,507	23,440
Total Assets	12,782				21,487				12,782	21,487	25,488
Additions to Net Property and Equipment	2,099				7,006				2,099	7,006	6,159
Canada [Member]
Segment Reporting Information [Line Items]
Oil and gas production revenues									498	1,092	1,224
Depreciation, depletion, and amortization									301	439	510
Exploration									231	162	86
Asset retirement obligation accretion									43	39	49
Lease operating expenses									244	384	459
Gathering and transportation									89	123	155
Taxes other than income									26	31	45
Impairments									1,593	2,412	274
Operating Income (Loss)									(2,029)	(2,498)	(354)
Other Income (Expense):
Net property and equipment	2,074				4,197				2,074	4,197	6,300
Total Assets	2,225				4,728				2,225	4,728	7,191
Additions to Net Property and Equipment	403				1,358				403	1,358	1,065
Egypt [Member]
Segment Reporting Information [Line Items]
Oil and gas production revenues									2,095	3,643	3,971
Depreciation, depletion, and amortization									927	872	880
Exploration									154	112	86
Lease operating expenses									522	499	471
Gathering and transportation									45	40	42
Taxes other than income									9	11	8
Impairments									1,255	173	12
Operating Income (Loss)									(817)	1,936	2,472
Other Income (Expense):
Net property and equipment	3,712				5,141				3,712	5,141	4,908
Total Assets	6,165				6,926				6,165	6,926	7,761
Additions to Net Property and Equipment	862				1,293				862	1,293	1,226
North Sea [Member]
Segment Reporting Information [Line Items]
Oil and gas production revenues									1,280	2,316	2,728
Depreciation, depletion, and amortization									514	807	976
Exploration									237	119	58
Asset retirement obligation accretion									74	72	68
Lease operating expenses									349	434	400
Gathering and transportation									9	17	7
Taxes other than income									63	185	384
Impairments									211	1,895	1,061
Operating Income (Loss)									(177)	(1,213)	(226)
Other Income (Expense):
Net property and equipment	3,263				3,300				3,263	3,300	5,064
Total Assets	4,280				4,480				4,280	4,480	6,334
Additions to Net Property and Equipment	715				1,060				715	1,060	1,078
Other International [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion, and amortization											1
Exploration									4	(7)	83
Impairments									147		0
Operating Income (Loss)									(151)	7	(84)
Other Income (Expense):
Net property and equipment	36				9				36	9	1
Total Assets	48				544				48	544	487
Additions to Net Property and Equipment	$ 27				$ 8				$ 27	$ 8	$ 1

Supplemental Oil and Gas Dis112

Supplemental Oil and Gas Disclosures (Unaudited) - Revenue and Direct Cost Information Relating to Company's Oil and Gas Exploration and Production Activities (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and gas production revenues	$ 6,510	$ 12,795	$ 14,825
Depreciation, depletion, and amortization(1)	2,976	4,195	4,705
Asset retirement obligation accretion	145	154	211
Lease operating expenses	1,854	2,238	2,650
Gathering and transportation	211	273	288
Exploration expenses	2,771	2,499	942
Impairments related to oil and gas properties	7,389	6,068	1,443
Production taxes	259	546	746
Income tax	(3,049)	(1,070)	1,640
Oil and gas properties production expense	12,556	14,903	12,625
Results of operation	(6,046)	(2,108)	2,200
United States [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and gas production revenues	2,637	5,744	6,902
Depreciation, depletion, and amortization(1)	1,455	2,294	2,579
Asset retirement obligation accretion	28	43	94
Lease operating expenses	739	921	1,320
Gathering and transportation	68	93	84
Exploration expenses	2,145	2,113	629
Impairments related to oil and gas properties	6,154	2,372	96
Production taxes	178	342	324
Income tax	(2,886)	(864)	630
Oil and gas properties production expense	7,881	7,314	5,756
Results of operation	(5,244)	(1,570)	1,146
Canada [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and gas production revenues	498	1,092	1,224
Depreciation, depletion, and amortization(1)	251	382	417
Asset retirement obligation accretion	43	39	49
Lease operating expenses	244	384	459
Gathering and transportation	89	123	155
Exploration expenses	231	162	86
Impairments related to oil and gas properties	1,031	1,645	274
Production taxes	23	27	40
Income tax	(369)	(421)	(63)
Oil and gas properties production expense	1,543	2,341	1,417
Results of operation	(1,045)	(1,249)	(193)
Egypt [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and gas production revenues	2,095	3,643	3,971
Depreciation, depletion, and amortization(1)	780	735	756
Lease operating expenses	522	499	471
Gathering and transportation	45	40	42
Exploration expenses	154	112	86
Impairments related to oil and gas properties	193	173	12
Income tax	180	938	1,198
Oil and gas properties production expense	1,874	2,497	2,565
Results of operation	221	1,146	1,406
North Sea [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and gas production revenues	1,280	2,316	2,728
Depreciation, depletion, and amortization(1)	490	784	953
Asset retirement obligation accretion	74	72	68
Lease operating expenses	349	434	400
Gathering and transportation	9	17	7
Exploration expenses	237	119	58
Impairments related to oil and gas properties	11	1,878	1,061
Production taxes	58	177	382
Income tax	26	(723)	(125)
Oil and gas properties production expense	1,254	2,758	2,804
Results of operation	26	(442)	(76)
Other International [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Exploration expenses	4	(7)	83
Impairments related to oil and gas properties		0	0
Oil and gas properties production expense	4	(7)	83
Results of operation	$ (4)	$ 7	$ (83)

Supplemental Oil and Gas Dis113

Supplemental Oil and Gas Disclosures (Unaudited) - Costs Incurred in Oil and Gas Property Acquisitions, Exploration and Development Activities (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved	$ 38	$ 113	$ 181
Unproved	336	1,378	385
Exploration	677	1,049	1,708
Development	3,198	8,941	8,326
Costs incurred	4,249	11,481	10,600
Proved properties	41,728	49,376
Unproved properties	2,277	5,490
Capitalized costs, gross	44,005	54,866
Accumulated DD&A	(24,457)	(24,431)
Capitalized costs, net	19,548	30,435
Capitalized interest	21	148	168
Asset retirement costs	65	307	537
United States [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved	1	102	17
Unproved	313	1,221	195
Exploration	194	505	617
Development	1,729	5,078	5,188
Costs incurred	2,237	6,906	6,017
Proved properties	18,692	22,791
Unproved properties	1,615	3,610
Capitalized costs, gross	20,307	26,401
Accumulated DD&A	(9,027)	(7,572)
Capitalized costs, net	11,280	18,829
Capitalized interest		17	50
Asset retirement costs	123	43	480
Canada [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved	8
Unproved	23	141	151
Exploration	51	93	35
Development	151	789	681
Costs incurred	233	1,023	867
Proved properties	5,812	6,659
Unproved properties	172	675
Capitalized costs, gross	5,984	7,334
Accumulated DD&A	(3,958)	(3,803)
Capitalized costs, net	2,026	3,531
Asset retirement costs	8	175	17
Egypt [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved	29	11	39
Unproved	0	0	11
Exploration	125	207	565
Development	741	1,122	599
Costs incurred	895	1,340	1,214
Proved properties	9,798	9,096
Unproved properties	25	179
Capitalized costs, gross	9,823	9,275
Accumulated DD&A	(6,559)	(5,779)
Capitalized costs, net	3,264	3,496
Capitalized interest	8	9	2
Australia [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved	0	0
Unproved		16	0
Exploration	32	131	168
Development	98	990	1,055
Costs incurred	130	1,137	1,223
Proved properties		3,919
Unproved properties		438
Capitalized costs, gross		4,357
Accumulated DD&A		(2,744)
Capitalized costs, net		1,613
Capitalized interest	6	90	74
Asset retirement costs		55	(30)
North Sea [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Proved			125
Unproved			17
Exploration	246	103	259
Development	479	956	661
Costs incurred	725	1,059	1,062
Proved properties	7,426	6,911
Unproved properties	429	579
Capitalized costs, gross	7,855	7,490
Accumulated DD&A	(4,913)	(4,533)
Capitalized costs, net	2,942	2,957
Capitalized interest	7	29	32
Asset retirement costs	(66)	34	67
Argentina [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Unproved			11
Exploration		9	42
Development		6	142
Costs incurred		15	195
Capitalized interest		3	10
Asset retirement costs			3
Other International [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Exploration	29	1	22
Costs incurred	29	1	$ 22
Proved properties	0	0
Unproved properties	36	9
Capitalized costs, gross	36	9
Accumulated DD&A	0	0
Capitalized costs, net	$ 36	$ 9

Supplemental Oil and Gas Dis114

Supplemental Oil and Gas Disclosures (Unaudited) - Proved Reserve Data (Detail)	12 Months Ended
	Dec. 31, 2015MMcfMBbls	Dec. 31, 2014MMcfMBbls	Dec. 31, 2013MMcfMBbls	Dec. 31, 2012MMcfMBbls
Reserve Quantities [Line Items]
Proved developed reserves	1,331,397	1,651,291	1,832,936	1,981,945
Proved undeveloped reserves	232,336	744,979	813,480	869,734
Beginning balance	2,396,270	2,646,416	2,851,679
Extensions, discoveries and other additions	117,405	313,095	389,336
Purchase of minerals in-place	6,860	21,712	5,976
Revisions of previous estimates	(365,135)	14,150	34,801
Production	(206,840)	(241,577)	(279,945)
Sale of properties	(384,827)	(357,526)	(355,431)
Ending balance	1,563,733	2,396,270	2,646,416
Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	275,033	236,256	222,880	221,819
Proved undeveloped reserves	26,929	43,446	48,028	51,464
Beginning balance	279,702	270,908	273,283
Extensions, discoveries and other additions	40,464	60,877	51,135
Purchase of minerals in-place			5
Revisions of previous estimates	37,825	5,522	3,121
Production	(56,029)	(57,605)	(56,636)
Ending balance	301,962	279,702	270,908
United States [Member]
Reserve Quantities [Line Items]
Proved developed reserves	726,424	897,422	976,795	1,021,610
Proved undeveloped reserves	120,210	336,670	370,566	402,677
Beginning balance	1,234,092	1,347,361	1,424,287
Extensions, discoveries and other additions	26,488	138,413	253,578
Purchase of minerals in-place		21,712	273
Revisions of previous estimates	(322,123)	11,662	13,482
Production	(91,591)	(106,225)	(121,074)
Sale of properties	(232)	(178,831)	(223,185)
Ending balance	846,634	1,234,092	1,347,361
Canada [Member]
Reserve Quantities [Line Items]
Proved developed reserves	209,647	258,848	322,362	390,800
Proved undeveloped reserves	70,300	155,028	139,509	150,113
Beginning balance	413,876	461,871	540,913
Extensions, discoveries and other additions	26,226	74,666	74,107
Purchase of minerals in-place	6,860
Revisions of previous estimates	(87,081)	(2,800)	18,274
Production	(24,706)	(28,313)	(39,177)
Sale of properties	(55,228)	(91,548)	(132,246)
Ending balance	279,947	413,876	461,871
Australia [Member]
Reserve Quantities [Line Items]
Proved developed reserves		136,707	126,948	128,395
Proved undeveloped reserves		186,534	199,240	213,811
Beginning balance	323,241	326,188	342,206
Extensions, discoveries and other additions		17,780	4,764
Revisions of previous estimates	12,549	(216)	(135)
Production	(8,503)	(20,511)	(20,647)
Sale of properties	(327,287)
Ending balance		323,241	326,188
North Sea [Member]
Reserve Quantities [Line Items]
Proved developed reserves	120,293	122,058	117,457	137,626
Proved undeveloped reserves	14,897	23,301	32,633	31,563
Beginning balance	145,359	150,090	169,189
Extensions, discoveries and other additions	24,227	21,354	2,001
Purchase of minerals in-place			5,698
Revisions of previous estimates	(6,305)	(18)	24
Production	(26,011)	(26,067)	(26,822)
Sale of properties	(2,080)
Ending balance	135,190	145,359	150,090
Argentina [Member]
Reserve Quantities [Line Items]
Proved developed reserves			66,494	81,695
Proved undeveloped reserves			23,504	20,106
Beginning balance		89,998	101,801
Extensions, discoveries and other additions		5	3,751
Revisions of previous estimates			35
Production		(2,856)	(15,589)
Sale of properties		(87,147)
Ending balance			89,998
Crude Oil and Condensate [Member]
Reserve Quantities [Line Items]
Proved developed reserves	665,063	784,770	794,795	825,811
Proved undeveloped reserves	127,996	289,499	336,690	356,814
Beginning balance	1,074,269	1,131,485	1,182,625
Extensions, discoveries and other additions	59,556	126,387	192,222
Purchase of minerals in-place	1,763	15,240	3,713
Revisions of previous estimates	(165,609)	4,693	1,726
Production	(108,491)	(118,412)	(126,708)
Sale of properties	(68,429)	(85,124)	(122,093)
Ending balance	793,059	1,074,269	1,131,485
Crude Oil and Condensate [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	144,164	128,712	119,242	106,746
Proved undeveloped reserves	17,856	14,617	16,302	17,288
Beginning balance	143,329	135,544	124,034
Extensions, discoveries and other additions	24,524	38,074	43,738
Purchase of minerals in-place			5
Revisions of previous estimates	27,330	2,645	650
Production	(33,163)	(32,934)	(32,883)
Ending balance	162,020	143,329	135,544
Crude Oil and Condensate [Member] | United States [Member]
Reserve Quantities [Line Items]
Proved developed reserves	348,797	444,440	457,981	474,837
Proved undeveloped reserves	60,505	170,125	195,835	203,068
Beginning balance	614,565	653,816	677,905
Extensions, discoveries and other additions	13,903	57,011	133,227
Purchase of minerals in-place		15,240	85
Revisions of previous estimates	(173,907)	3,083	1,683
Production	(45,138)	(48,789)	(53,621)
Sale of properties	(121)	(65,796)	(105,463)
Ending balance	409,302	614,565	653,816
Crude Oil and Condensate [Member] | Canada [Member]
Reserve Quantities [Line Items]
Proved developed reserves	67,847	75,876	80,526	79,695
Proved undeveloped reserves	38,326	59,923	56,366	70,650
Beginning balance	135,799	136,892	150,345
Extensions, discoveries and other additions	4,550	9,657	10,177
Purchase of minerals in-place	1,763
Revisions of previous estimates	(27,966)	(812)	(531)
Production	(5,755)	(6,421)	(6,469)
Sale of properties	(2,218)	(3,517)	(16,630)
Ending balance	106,173	135,799	136,892
Crude Oil and Condensate [Member] | Australia [Member]
Reserve Quantities [Line Items]
Proved developed reserves		29,996	22,524	29,053
Proved undeveloped reserves		25,775	36,703	34,808
Beginning balance	55,771	59,227	63,861
Extensions, discoveries and other additions		4,254	2,539
Revisions of previous estimates	11,189	(216)	(118)
Production	(2,778)	(7,494)	(7,055)
Sale of properties	(64,182)
Ending balance		55,771	59,227
Crude Oil and Condensate [Member] | North Sea [Member]
Reserve Quantities [Line Items]
Proved developed reserves	104,255	105,746	100,327	119,635
Proved undeveloped reserves	11,309	19,059	29,253	28,019
Beginning balance	124,805	129,580	147,654
Extensions, discoveries and other additions	16,579	17,386	1,543
Purchase of minerals in-place			3,623
Revisions of previous estimates	(2,255)	(7)	18
Production	(21,657)	(22,154)	(23,258)
Sale of properties	(1,908)
Ending balance	115,564	124,805	129,580
Crude Oil and Condensate [Member] | Argentina [Member]
Reserve Quantities [Line Items]
Proved developed reserves			14,195	15,845
Proved undeveloped reserves			2,231	2,981
Beginning balance		16,426	18,826
Extensions, discoveries and other additions		5	998
Revisions of previous estimates			24
Production		(620)	(3,422)
Sale of properties		(15,811)
Ending balance			16,426
Natural Gas Liquids [Member]
Reserve Quantities [Line Items]
Proved developed reserves	168,786	204,628	217,129	183,949
Proved undeveloped reserves	30,151	77,579	74,732	74,403
Beginning balance	282,207	291,861	258,352
Extensions, discoveries and other additions	8,074	50,500	73,245
Purchase of minerals in-place	976	2,916	340
Revisions of previous estimates	(69,178)	2,697	2,141
Production	(22,721)	(24,595)	(23,595)
Sale of properties	(421)	(41,172)	(18,622)
Ending balance	198,937	282,207	291,861
Natural Gas Liquids [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	1,491	1,346
Proved undeveloped reserves	78	212
Beginning balance	1,558
Extensions, discoveries and other additions	144	1,820
Revisions of previous estimates	255	(11)
Production	(388)	(251)
Ending balance	1,569	1,558
Natural Gas Liquids [Member] | United States [Member]
Reserve Quantities [Line Items]
Proved developed reserves	150,265	183,565	184,485	154,508
Proved undeveloped reserves	24,939	69,828	63,538	60,889
Beginning balance	253,393	248,023	215,397
Extensions, discoveries and other additions	5,768	47,516	69,231
Purchase of minerals in-place		2,916	45
Revisions of previous estimates	(64,226)	2,594	1,591
Production	(19,684)	(21,464)	(19,922)
Sale of properties	(47)	(26,192)	(18,319)
Ending balance	175,204	253,393	248,023
Natural Gas Liquids [Member] | Canada [Member]
Reserve Quantities [Line Items]
Proved developed reserves	15,246	17,947	26,099	21,996
Proved undeveloped reserves	4,839	7,168	9,970	12,258
Beginning balance	25,115	36,069	34,254
Extensions, discoveries and other additions	1,473	1,163	4,014
Purchase of minerals in-place	976
Revisions of previous estimates	(4,886)	116	546
Production	(2,236)	(2,256)	(2,442)
Sale of properties	(357)	(9,977)	(303)
Ending balance	20,085	25,115	36,069
Natural Gas Liquids [Member] | North Sea [Member]
Reserve Quantities [Line Items]
Proved developed reserves	1,784	1,770	2,435	2,438
Proved undeveloped reserves	295	371	215	380
Beginning balance	2,141	2,650	2,818
Extensions, discoveries and other additions	689	1
Purchase of minerals in-place			295
Revisions of previous estimates	(321)	(2)	1
Production	(413)	(508)	(464)
Sale of properties	(17)
Ending balance	2,079	2,141	2,650
Natural Gas Liquids [Member] | Argentina [Member]
Reserve Quantities [Line Items]
Proved developed reserves			4,110	5,007
Proved undeveloped reserves			1,009	876
Beginning balance		5,119	5,883
Revisions of previous estimates			3
Production		(116)	(767)
Sale of properties		(5,003)
Ending balance			5,119
Natural Gas [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	2,985,290	3,971,360	4,926,064	5,833,105
Proved undeveloped reserves | MMcf	445,132	2,267,400	2,412,348	2,631,101
Beginning balance | MMcf	6,238,760	7,338,412	8,464,206
Extensions, discoveries and other additions | MMcf	298,649	817,253	743,212
Purchase of minerals in-place | MMcf	24,727	21,337	11,535
Revisions of previous estimates | MMcf	(782,083)	40,556	185,602
Production | MMcf	(453,772)	(591,420)	(777,848)
Sale of properties | MMcf	(1,895,859)	(1,387,378)	(1,288,295)
Ending balance | MMcf	3,430,422	6,238,760	7,338,412
Natural Gas [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	776,263	637,187	621,825	690,436
Proved undeveloped reserves | MMcf	53,969	171,696	190,355	205,055
Beginning balance | MMcf	808,883	812,180	895,491
Extensions, discoveries and other additions | MMcf	94,777	125,899	44,382
Revisions of previous estimates | MMcf	61,442	17,326	14,824
Production | MMcf	(134,870)	(146,522)	(142,517)
Ending balance | MMcf	830,232	808,883	812,180
Natural Gas [Member] | United States [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	1,364,174	1,616,504	2,005,966	2,353,587
Proved undeveloped reserves | MMcf	208,594	580,299	667,160	832,320
Beginning balance | MMcf	2,196,803	2,673,126	3,185,907
Extensions, discoveries and other additions | MMcf	40,901	203,318	306,721
Purchase of minerals in-place | MMcf		21,337	855
Revisions of previous estimates | MMcf	(503,939)	35,910	61,247
Production | MMcf	(160,614)	(215,829)	(285,187)
Sale of properties | MMcf	(383)	(521,059)	(596,417)
Ending balance | MMcf	1,572,768	2,196,803	2,673,126
Natural Gas [Member] | Canada [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	759,321	990,145	1,294,420	1,734,657
Proved undeveloped reserves | MMcf	162,809	527,623	439,037	403,227
Beginning balance | MMcf	1,517,768	1,733,457	2,137,884
Extensions, discoveries and other additions | MMcf	121,216	383,077	359,493
Purchase of minerals in-place | MMcf	24,727
Revisions of previous estimates | MMcf	(325,375)	(12,626)	109,551
Production | MMcf	(100,289)	(117,816)	(181,593)
Sale of properties | MMcf	(315,917)	(468,324)	(691,878)
Ending balance | MMcf	922,130	1,517,768	1,733,457
Natural Gas [Member] | Australia [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf		640,265	626,543	596,052
Proved undeveloped reserves | MMcf		964,554	975,224	1,074,018
Beginning balance | MMcf	1,604,819	1,601,767	1,670,070
Extensions, discoveries and other additions | MMcf		81,156	13,351
Revisions of previous estimates | MMcf	8,162		(101)
Production | MMcf	(34,352)	(78,104)	(81,553)
Sale of properties | MMcf	(1,578,629)
Ending balance | MMcf		1,604,819	1,601,767
Natural Gas [Member] | North Sea [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	85,532	87,259	88,177	93,319
Proved undeveloped reserves | MMcf	19,760	23,228	18,988	18,985
Beginning balance | MMcf	110,487	107,165	112,304
Extensions, discoveries and other additions | MMcf	41,755	23,803	2,750
Purchase of minerals in-place | MMcf			10,680
Revisions of previous estimates | MMcf	(22,373)	(54)	32
Production | MMcf	(23,647)	(20,427)	(18,601)
Sale of properties | MMcf	(930)
Ending balance | MMcf	105,292	110,487	107,165
Natural Gas [Member] | Argentina [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf			289,133	365,054
Proved undeveloped reserves | MMcf			121,584	97,496
Beginning balance | MMcf		410,717	462,550
Extensions, discoveries and other additions | MMcf			16,515
Revisions of previous estimates | MMcf			49
Production | MMcf		(12,722)	(68,397)
Sale of properties | MMcf		(397,995)
Ending balance | MMcf			410,717

Supplemental Oil and Gas Dis115

Supplemental Oil and Gas Disclosures (Unaudited) - Proved Reserve Data (Parenthetical) (Detail)	Dec. 31, 2015MMBoeMMcfMBbls	Dec. 31, 2014MMBoeMMcfMBbls	Dec. 31, 2013MMBoeMMcfMBbls	Dec. 31, 2012MMcfMBbls
Reserve Quantities [Line Items]
Proved developed reserves	1,331,397	1,651,291	1,832,936	1,981,945
Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	275,033	236,256	222,880	221,819
Egypt [Member] | Noncontrolling Interest [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMBoe	101	93	90
Crude Oil and Condensate [Member]
Reserve Quantities [Line Items]
Proved developed reserves	665,063	784,770	794,795	825,811
Crude Oil and Condensate [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	144,164	128,712	119,242	106,746
Crude Oil and Condensate [Member] | Egypt [Member] | Noncontrolling Interest [Member]
Reserve Quantities [Line Items]
Proved developed reserves	54	48	45
Natural Gas Liquids [Member]
Reserve Quantities [Line Items]
Proved developed reserves	168,786	204,628	217,129	183,949
Natural Gas Liquids [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves	1,491	1,346
Natural Gas Liquids [Member] | Egypt [Member] | Noncontrolling Interest [Member]
Reserve Quantities [Line Items]
Proved developed reserves	523	519
Natural Gas [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	2,985,290	3,971,360	4,926,064	5,833,105
Natural Gas [Member] | Egypt [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	776,263	637,187	621,825	690,436
Natural Gas [Member] | Egypt [Member] | Noncontrolling Interest [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	277	270	271

Supplemental Oil and Gas Dis116

Supplemental Oil and Gas Disclosures (Unaudited) - Unaudited Information of Future Net Cash Flows For Oil and Gas Reserves, Net of Income Tax Expense (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows	$ 52,073	$ 142,934
Production costs	(21,413)	(47,562)
Development costs	(8,055)	(12,507)
Income tax expense	(3,080)	(21,465)
Net cash flows	19,525	61,400
10 percent discount rate	(8,931)	(29,742)
Discounted future net cash flows	10,594	31,658
Egypt [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows	11,124	16,802
Production costs	(2,185)	(2,924)
Development costs	(1,515)	(1,683)
Income tax expense	(2,326)	(4,091)
Net cash flows	5,098	8,104
10 percent discount rate	(1,330)	(2,099)
Discounted future net cash flows	3,768	6,005
United States [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows	26,610	73,859
Production costs	(12,178)	(25,875)
Development costs	(2,255)	(4,422)
Income tax expense	(63)	(10,657)
Net cash flows	12,114	32,905
10 percent discount rate	(6,876)	(17,639)
Discounted future net cash flows	5,238	15,266
Canada [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows	7,345	18,966
Production costs	(3,841)	(7,537)
Development costs	(1,939)	(2,453)
Income tax expense		(1,070)
Net cash flows	1,565	7,906
10 percent discount rate	(868)	(3,983)
Discounted future net cash flows	697	3,923
Australia [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows		19,391
Production costs		(4,105)
Development costs		(1,173)
Income tax expense		(3,202)
Net cash flows		10,911
10 percent discount rate		(5,875)
Discounted future net cash flows		5,036
North Sea [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Cash inflows	6,994	13,916
Production costs	(3,209)	(7,121)
Development costs	(2,346)	(2,776)
Income tax expense	(691)	(2,445)
Net cash flows	748	1,574
10 percent discount rate	143	(146)
Discounted future net cash flows	$ 891	$ 1,428

Supplemental Oil and Gas Dis117

Supplemental Oil and Gas Disclosures (Unaudited) - Unaudited Information of Future Net Cash Flows For Oil and Gas Reserves, Net of Income Tax Expense (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Estimated future net cash flow before income tax expenses	10.00%
Total estimated future net cash flows before income tax expense discounted at 10 percent per annum	$ 13,100	$ 43,000
Total estimated future net cash flows	10,594	31,658
Egypt [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Total estimated future net cash flows	3,768	6,005
Egypt [Member] | Noncontrolling Interest [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Total estimated future net cash flows	$ 1,300	$ 2,000

Supplemental Oil and Gas Dis118

Supplemental Oil and Gas Disclosures (Unaudited) - Principal Sources of Change In Discounted Future Net Cash Flows (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Sales, net of production costs	$ (4,056)	$ (10,350)	$ (12,271)
Net change in prices and production costs	(21,710)	(1,029)	1,438
Discoveries and improved recovery, net of related costs	1,953	6,297	6,892
Change in future development costs	705	(1,136)	(2,017)
Previously estimated development costs incurred during the period	1,991	4,462	4,654
Revision of quantities	(2,292)	256	500
Purchases of minerals in-place	22	508	227
Accretion of discount	3,642	4,442	4,823
Change in income taxes	7,264	836	855
Sales of properties	(5,240)	(4,780)	(6,232)
Change in production rates and other	(3,343)	(442)	(828)
Change in the discounted future net cash flows, Total	$ (21,064)	$ (936)	$ (1,959)

Supplemental Oil and Gas Dis119

Supplemental Oil and Gas Disclosures (Unaudited) - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015MMBoeMBbls	Dec. 31, 2014MBbls	Dec. 31, 2013MBbls
Reserve Quantities [Line Items]
Purchases of minerals in-place	7
Sale of minerals in-place through divestiture transactions	385
Extensions, discoveries and other additions | MMBoe	117
Combined downward revisions of previously estimated reserves	365
Changes in reserves accounted	(365,135)	14,150	34,801
Percentage of estimated proved developed reserves classified as proved not producing	9.00%
North America [Member]
Reserve Quantities [Line Items]
Extensions, discoveries and other additions | MMBoe	53
Canada [Member]
Reserve Quantities [Line Items]
Sale of minerals in-place through divestiture transactions	55
Changes in reserves accounted	(87,081)	(2,800)	18,274
Egypt [Member]
Reserve Quantities [Line Items]
Extensions, discoveries and other additions | MMBoe	40
Changes in reserves accounted	37,825	5,522	3,121
North Sea [Member]
Reserve Quantities [Line Items]
Sale of minerals in-place through divestiture transactions	2
Extensions, discoveries and other additions | MMBoe	24
Changes in reserves accounted	(6,305)	(18)	24
Australia [Member]
Reserve Quantities [Line Items]
Sale of minerals in-place through divestiture transactions	328
Changes in reserves accounted	12,549	(216)	(135)
International Regions [Member]
Reserve Quantities [Line Items]
Extensions, discoveries and other additions | MMBoe	64
Changes in Product Prices [Member]
Reserve Quantities [Line Items]
Changes in reserves accounted	339
Changes in Lease Ownership [Member]
Reserve Quantities [Line Items]
Changes in reserves accounted	16
Changes in Engineering and Performance [Member]
Reserve Quantities [Line Items]
Changes in reserves accounted	10

Supplemental Quarterly Finan120

Supplemental Quarterly Financial Data (Unaudited) - Supplemental Quarterly Financial Data (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]
Revenues and other	$ 1,405	$ 1,531	$ 2,019	$ 1,653	$ 2,858	$ 3,476	$ 3,323	$ 3,423	$ 6,608	$ 13,080
Gain (loss) on divestiture	77	(5)	227	(18)	(824)	0	(787)	3	281	(1,608)	$ (1,231)
Expenses	6,537	5,645	3,163	2,703	8,342	3,817	2,839	2,786	18,048	17,784
Net income (loss) from continuing operations including noncontrolling interest	(5,055)	(4,119)	(917)	(1,068)	(6,308)	(341)	(303)	640	(11,159)	(6,312)	6
Net income (loss) from discontinued operations, net of tax	627	(17)	120	(238)	(983)	(247)	68	(545)	492	(1,707)	438
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(4,428)	(4,136)	(797)	(1,306)	(7,291)	(588)	(235)	95	(10,667)	(8,019)	444
Net income (loss) attributable to common stock	$ (4,015)	$ (4,143)	$ (860)	$ (1,334)	$ (7,297)	$ (691)	$ (354)	$ (18)	$ (10,352)	$ (8,360)	$ 344
Basic net income (loss) per common share
Net income (loss) from continuing operations	$ (12.28)	$ (10.91)	$ (2.60)	$ (2.91)	$ (16.77)	$ (1.17)	$ (1.10)	$ 1.35	$ (28.70)	$ (17.32)	$ (0.24)
Net income (loss) from discontinued operations	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Net income (loss) per share	(10.62)	(10.95)	(2.28)	(3.54)	(19.38)	(1.82)	(0.92)	(0.03)	(27.40)	(21.76)	0.87
DILUTED NET INCOME (LOSS) PER COMMON SHARE
Net income (loss) from continuing operations	(12.28)	(10.91)	(2.60)	(2.91)	(16.77)	(1.17)	(1.10)	1.35	(28.70)	(17.32)	(0.24)
Net income (loss) from discontinued operations	1.66	(0.04)	0.32	(0.63)	(2.61)	(0.65)	0.18	(1.38)	1.30	(4.44)	1.11
Net income (loss) per share	$ (10.62)	$ (10.95)	$ (2.28)	$ (3.54)	$ (19.38)	$ (1.82)	$ (0.92)	$ (0.03)	$ (27.40)	$ (21.76)	$ 0.87
Asset impairments	$ 5,100	$ 4,100	$ 660	$ 2,100	$ 8,700	$ 123	$ 162	$ 115	$ 9,472	$ 7,102	$ 1,443

Supplemental Guarantor Infor121

Supplemental Guarantor Information - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Condensed Financial Statements, Captions [Line Items]
Equity ownership percentage	100.00%
Notes Due 2029 [Member]
Condensed Financial Statements, Captions [Line Items]
Publicly traded notes	$ 300
Publicly-traded notes maturity date	2,029

Supplemental Guarantor Infor122

Supplemental Guarantor Information - Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income (Detail) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
REVENUES AND OTHER:
Oil and gas production revenues									$ 6,510	$ 12,795	$ 14,825
Other									98	285	(315)
Gain (loss) on divestiture	$ 77	$ (5)	$ 227	$ (18)	$ (824)	$ 0	$ (787)	$ 3	281	(1,608)	(1,231)
Total revenues and other									6,889	11,472	13,279
OPERATING EXPENSES:
Lease operating expenses									1,854	2,238	2,650
Gathering and transportation									211	273	288
Taxes other than income									282	577	772
Exploration									2,771	2,499	942
General and administrative									380	453	491
Depreciation, depletion, and amortization									3,300	4,526	5,057
Asset retirement obligation accretion									145	154	211
Asset impairments	5,100	4,100	660	2,100	8,700	123	162	115	9,472	7,102	1,443
Transaction, reorganization, and separation									132	67	33
Financing costs, net									511	413	445
Total operating expenses									19,058	18,302	12,332
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									(12,169)	(6,830)	947
Provision (benefit) for income taxes									(1,010)	(518)	941
Net income (loss) from continuing operations including noncontrolling interest	(5,055)	(4,119)	(917)	(1,068)	(6,308)	(341)	(303)	640	(11,159)	(6,312)	6
Net income (loss) from discontinued operations, net of tax	627	(17)	120	(238)	(983)	(247)	68	(545)	492	(1,707)	438
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(4,428)	(4,136)	(797)	(1,306)	(7,291)	(588)	(235)	95	(10,667)	(8,019)	444
Preferred stock dividends									0	0	44
Net income attributable to noncontrolling interest									(315)	341	56
Net income (loss) attributable to common shareholders	$ (4,015)	$ (4,143)	$ (860)	$ (1,334)	$ (7,297)	$ (691)	$ (354)	$ (18)	(10,352)	(8,360)	344
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(10,355)	(8,361)	360
Reclassifications & Eliminations [Member]
REVENUES AND OTHER:
Equity in net income (loss) of affiliates									5,937	4,607	(788)
Other									19	5	(4)
Total revenues and other									5,956	4,612	(792)
OPERATING EXPENSES:
General and administrative									19	5	(4)
Total operating expenses									19	5	(4)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									5,937	4,607	(788)
Net income (loss) from continuing operations including noncontrolling interest									5,937	4,607	(788)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									5,937	4,607	(788)
Net income (loss) attributable to common shareholders									5,937	4,607	(788)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									5,937	4,607	(788)
Apache Corporation [Member]
REVENUES AND OTHER:
Oil and gas production revenues									1,446	3,399	4,585
Equity in net income (loss) of affiliates									(5,254)	(3,489)	722
Other									(71)	375	(399)
Gain (loss) on divestiture									36	(1,031)	(670)
Total revenues and other									(3,843)	(746)	4,238
OPERATING EXPENSES:
Lease operating expenses									399	509	939
Gathering and transportation									35	58	61
Taxes other than income									103	206	190
Exploration									2,096	1,966	332
General and administrative									296	370	411
Depreciation, depletion, and amortization									966	1,493	1,668
Asset retirement obligation accretion									15	31	67
Asset impairments									3,885	1,626	60
Transaction, reorganization, and separation									132	67	33
Financing costs, net									475	372	339
Total operating expenses									8,402	6,698	4,100
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									(12,245)	(7,444)	138
Provision (benefit) for income taxes									(2,065)	789	(250)
Net income (loss) from continuing operations including noncontrolling interest									(10,180)	(8,233)	388
Net income (loss) from discontinued operations, net of tax									(172)	(127)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									(10,352)	(8,360)	388
Preferred stock dividends											44
Net income (loss) attributable to common shareholders									(10,352)	(8,360)	344
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(10,355)	(8,361)	360
Apache Finance Canada [Member]
REVENUES AND OTHER:
Equity in net income (loss) of affiliates									(740)	(1,191)	30
Other									54	55	61
Total revenues and other									(686)	(1,136)	91
OPERATING EXPENSES:
Financing costs, net									(14)	(24)	5
Total operating expenses									(14)	(24)	5
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									(672)	(1,112)	86
Provision (benefit) for income taxes									11	6	20
Net income (loss) from continuing operations including noncontrolling interest									(683)	(1,118)	66
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									(683)	(1,118)	66
Net income (loss) attributable to common shareholders									(683)	(1,118)	66
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									(683)	(1,118)	66
All Other Subsidiaries of Apache Corporation [Member]
REVENUES AND OTHER:
Oil and gas production revenues									5,064	9,396	10,240
Equity in net income (loss) of affiliates									57	73	36
Other									96	(150)	27
Gain (loss) on divestiture									245	(577)	(561)
Total revenues and other									5,462	8,742	9,742
OPERATING EXPENSES:
Lease operating expenses									1,455	1,729	1,711
Gathering and transportation									176	215	227
Taxes other than income									179	371	582
Exploration									675	533	610
General and administrative									65	78	84
Depreciation, depletion, and amortization									2,334	3,033	3,389
Asset retirement obligation accretion									130	123	144
Asset impairments									5,587	5,476	1,383
Financing costs, net									50	65	101
Total operating expenses									10,651	11,623	8,231
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES									(5,189)	(2,881)	1,511
Provision (benefit) for income taxes									1,044	(1,313)	1,171
Net income (loss) from continuing operations including noncontrolling interest									(6,233)	(1,568)	340
Net income (loss) from discontinued operations, net of tax									664	(1,580)	438
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST									(5,569)	(3,148)	778
Net income attributable to noncontrolling interest									(315)	341	56
Net income (loss) attributable to common shareholders									(5,254)	(3,489)	722
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK									$ (5,254)	$ (3,489)	$ 722

Supplemental Guarantor Infor123

Supplemental Guarantor Information - Supplemental Condensed Consolidating Statement of Cash Flows (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	$ 2,554	$ 7,013	$ 8,264
CASH PROVIDED BY DISCONTINUED OPERATIONS	113	944	1,164
CASH PROVIDED BY OPERATING ACTIVITIES	2,667	7,957	9,428
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(4,208)	(8,608)	(8,242)
Additions to gas gathering, transmission, and processing facilities	(233)	(881)	(464)
Proceeds from sale of Deepwater Gulf of Mexico assets	854	1,360
Proceeds from divestiture of Gulf of Mexico Shelf properties	391	1,262	3,702
Leasehold and property acquisitions	(367)	(1,475)	(429)
Proceeds from Kitimat LNG transaction, net			396
Proceeds from sale of oil and gas assets	268	470	307
Other	6	(299)	(105)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	3,289	8,171	4,835
NET CASH PROVIDED BY DISCONTINUED OPERATIONS	4,372	(219)	(1,874)
NET CASH USED IN INVESTING ACTIVITIES	1,083	(8,390)	(6,709)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper, credit facility, and bank notes, net	(1,570)	1,568	(509)
Payments on fixed rate debt	(939)		(2,072)
Dividends paid	(377)	(365)	(360)
Distributions to noncontrolling interest	(129)	(140)
Proceeds from sale of noncontrolling interest			2,948
Shares repurchased		(1,864)	(997)
Other	53	49	21
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	(2,962)	(752)	(969)
NET CASH USED IN DISCONTINUED OPERATIONS		(42)	(4)
NET CASH USED IN FINANCING ACTIVITIES	(2,962)	(794)	(973)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	788	(1,227)	1,746
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	679	1,906	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	1,467	679	1,906
Reclassifications & Eliminations [Member]
CASH FLOWS FROM INVESTING ACTIVITIES:
Investment in subsidiaries, net	(6,363)	(1,132)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	6,363	1,132
NET CASH USED IN INVESTING ACTIVITIES	(6,363)	(1,132)
CASH FLOWS FROM FINANCING ACTIVITIES:
Intercompany borrowings	6,363	1,144
Other		(12)
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	6,363	1,132
NET CASH USED IN FINANCING ACTIVITIES	6,363	1,132
Apache Corporation [Member]
Condensed Financial Statements, Captions [Line Items]
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	98	3,104	1,076
CASH PROVIDED BY OPERATING ACTIVITIES	98	3,104	1,076
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(1,500)	(4,364)	(3,751)
Additions to gas gathering, transmission, and processing facilities	(156)	(9)	(124)
Proceeds from sale of Deepwater Gulf of Mexico assets		1,360
Proceeds from divestiture of Gulf of Mexico Shelf properties		1,262	3,702
Leasehold and property acquisitions	(313)	(1,475)	(195)
Proceeds from sale of oil and gas assets	163	15
Investment in subsidiaries, net	6,363	1,132
Other	(34)	(186)	(58)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	(4,523)	2,265	426
NET CASH USED IN INVESTING ACTIVITIES	4,523	(2,265)	(426)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper, credit facility, and bank notes, net	(1,570)	1,570	(501)
Intercompany borrowings	(1,621)		3,056
Payments on fixed rate debt	(939)		(1,722)
Dividends paid	(377)	(365)	(360)
Shares repurchased		(1,864)	(997)
Other	(3)	(68)	29
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	(4,510)	(727)	(495)
NET CASH USED IN FINANCING ACTIVITIES	(4,510)	(727)	(495)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	111	112	155
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	267	155
CASH AND CASH EQUIVALENTS AT END OF PERIOD	378	267	155
Apache Finance Canada [Member]
Condensed Financial Statements, Captions [Line Items]
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	18	17	315
CASH PROVIDED BY OPERATING ACTIVITIES	18	17	315
CASH FLOWS FROM FINANCING ACTIVITIES:
Intercompany borrowings	(18)	8	1
Payments on fixed rate debt			(350)
Other		(28)	37
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	(18)	(20)	(312)
NET CASH USED IN FINANCING ACTIVITIES	(18)	(20)	(312)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	0	(3)	3
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR		3
CASH AND CASH EQUIVALENTS AT END OF PERIOD	0		3
All Other Subsidiaries of Apache Corporation [Member]
Condensed Financial Statements, Captions [Line Items]
CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	2,438	3,892	6,873
CASH PROVIDED BY DISCONTINUED OPERATIONS	113	944	1,164
CASH PROVIDED BY OPERATING ACTIVITIES	2,551	4,836	8,037
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(2,708)	(4,244)	(4,491)
Additions to gas gathering, transmission, and processing facilities	(77)	(872)	(340)
Proceeds from sale of Deepwater Gulf of Mexico assets	854
Proceeds from divestiture of Gulf of Mexico Shelf properties	391
Leasehold and property acquisitions	(54)	0	(234)
Proceeds from Kitimat LNG transaction, net			396
Proceeds from sale of oil and gas assets	105	455	307
Other	40	(113)	(47)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	1,449	4,774	4,409
NET CASH PROVIDED BY DISCONTINUED OPERATIONS	4,372	(219)	(1,874)
NET CASH USED IN INVESTING ACTIVITIES	2,923	(4,993)	(6,283)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper, credit facility, and bank notes, net		(2)	(8)
Intercompany borrowings	(4,724)	(1,152)	(3,057)
Distributions to noncontrolling interest	(129)	(140)
Proceeds from sale of noncontrolling interest			2,948
Other	56	157	(45)
NET CASH USED IN CONTINUING FINANCING ACTIVITIES	(4,797)	(1,137)	(162)
NET CASH USED IN DISCONTINUED OPERATIONS		(42)	(4)
NET CASH USED IN FINANCING ACTIVITIES	(4,797)	(1,179)	(166)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	677	(1,336)	1,588
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	412	1,748	160
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$ 1,089	$ 412	$ 1,748

Supplemental Guarantor Infor124

Supplemental Guarantor Information - Supplemental Condensed Consolidating Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS:
Cash and cash equivalents	$ 1,467	$ 679	$ 1,906	$ 160
Receivables, net of allowance	1,253	2,019
Inventories	570	681
Drilling advances	172	283
Assets held for sale		3,381
Deferred tax asset		890
Prepaid assets and other	290	129
Total current assets	3,752	8,062
PROPERTY AND EQUIPMENT, NET	20,838	34,645
OTHER ASSETS:
Deferred charges and other	910	1,557
Total assets	25,500	44,264
CURRENT LIABILITIES:
Accounts payable	618	1,110
Liabilities held for sale		428
Other current liabilities	1,223	2,240
Total current liabilities	1,841	3,778
Long-term debt	8,716	11,178
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	2,529	5,493
Asset retirement obligation, non current	2,562	2,915
Other	362	359
Total deferred credits and other noncurrent liabilities	5,453	8,767
COMMITMENTS AND CONTINGENCIES
APACHE SHAREHOLDERS' EQUITY	7,888	18,495
Noncontrolling interest	1,602	2,046
TOTAL EQUITY	9,490	20,541	30,756	28,538
Total liabilities and shareholders' equity	25,500	44,264
Reclassifications & Eliminations [Member]
CURRENT ASSETS:
Intercompany receivable	(5,212)	(4,939)
Total current assets	(5,212)	(4,939)
OTHER ASSETS:
Intercompany receivable	(10,744)	(4,821)
Equity in affiliates	(15,731)	(21,668)
Deferred charges and other	(1,000)	(1,000)
Total assets	(32,687)	(32,428)
CURRENT LIABILITIES:
Intercompany payable	(5,212)	(4,939)
Total current liabilities	(5,212)	(4,939)
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable	(10,744)	(4,821)
Other	(1,000)	(1,000)
Total deferred credits and other noncurrent liabilities	(11,744)	(5,821)
APACHE SHAREHOLDERS' EQUITY	(15,731)	(21,668)
TOTAL EQUITY	(15,731)	(21,668)
Total liabilities and shareholders' equity	(32,687)	(32,428)
Apache Corporation [Member]
CURRENT ASSETS:
Cash and cash equivalents	378	267	155
Receivables, net of allowance	314	837
Inventories	34	24
Drilling advances	16	34
Deferred tax asset		612
Prepaid assets and other	102	32
Intercompany receivable	5,212	4,939
Total current assets	6,056	6,745
PROPERTY AND EQUIPMENT, NET	6,546	12,146
OTHER ASSETS:
Intercompany receivable		819
Equity in affiliates	16,092	21,346
Deferred charges and other	96	108
Total assets	28,790	41,164
CURRENT LIABILITIES:
Accounts payable	409	748
Other current liabilities	539	1,042
Total current liabilities	948	1,790
Long-term debt	8,418	10,880
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable	10,744	3,882
Income taxes	(412)	3,824
Asset retirement obligation, non current	271	211
Other	933	2,082
Total deferred credits and other noncurrent liabilities	11,536	9,999
APACHE SHAREHOLDERS' EQUITY	7,888	18,495
TOTAL EQUITY	7,888	18,495
Total liabilities and shareholders' equity	28,790	41,164
Apache Finance Canada [Member]
CURRENT ASSETS:
Cash and cash equivalents	0		3
Drilling advances		1
Total current assets		1
OTHER ASSETS:
Equity in affiliates	(807)	(2)
Deferred charges and other	1,001	1,002
Total assets	194	1,001
CURRENT LIABILITIES:
Accounts payable		10
Other current liabilities	3	1
Total current liabilities	3	11
Long-term debt	298	298
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable		120
Income taxes	4
Other	250	250
Total deferred credits and other noncurrent liabilities	254	370
APACHE SHAREHOLDERS' EQUITY	(361)	322
TOTAL EQUITY	(361)	322
Total liabilities and shareholders' equity	194	1,001
All Other Subsidiaries of Apache Corporation [Member]
CURRENT ASSETS:
Cash and cash equivalents	1,089	412	$ 1,748	$ 160
Receivables, net of allowance	939	1,182
Inventories	536	657
Drilling advances	156	248
Assets held for sale		3,381
Deferred tax asset		278
Prepaid assets and other	188	97
Total current assets	2,908	6,255
PROPERTY AND EQUIPMENT, NET	14,292	22,499
OTHER ASSETS:
Intercompany receivable	10,744	4,002
Equity in affiliates	446	324
Deferred charges and other	813	1,447
Total assets	29,203	34,527
CURRENT LIABILITIES:
Accounts payable	209	352
Liabilities held for sale		428
Other current liabilities	681	1,197
Intercompany payable	5,212	4,939
Total current liabilities	6,102	6,916
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable		819
Income taxes	2,937	1,669
Asset retirement obligation, non current	2,291	2,704
Other	179	(973)
Total deferred credits and other noncurrent liabilities	5,407	4,219
APACHE SHAREHOLDERS' EQUITY	16,092	21,346
Noncontrolling interest	1,602	2,046
TOTAL EQUITY	17,694	23,392
Total liabilities and shareholders' equity	$ 29,203	$ 34,527