Apache 10-Q 3 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Oct. 31, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q3
Trading Symbol	APA
Entity Registrant Name	APACHE CORP
Entity Central Index Key	6,769
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		380,942,629

STATEMENT OF CONSOLIDATED OPERA

STATEMENT OF CONSOLIDATED OPERATIONS (Unaudited) - USD ($) shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
REVENUES AND OTHER:
Oil and Gas Production Revenues	$ 1,389,000,000	$ 1,439,000,000	$ 4,247,000,000	$ 3,912,000,000
Derivative instrument losses, net	(110,000,000)	0	(69,000,000)	0
Gain on divestitures	296,000,000	5,000,000	616,000,000	21,000,000
Other	0	(6,000,000)	43,000,000	(30,000,000)
Total revenues and other	1,575,000,000	1,438,000,000	4,837,000,000	3,903,000,000
OPERATING EXPENSES:
Lease operating expenses	358,000,000	382,000,000	1,066,000,000	1,119,000,000
Gathering and transportation	39,000,000	51,000,000	144,000,000	155,000,000
Taxes other than income	46,000,000	9,000,000	117,000,000	85,000,000
Exploration	231,000,000	161,000,000	431,000,000	347,000,000
General and administrative	98,000,000	102,000,000	307,000,000	298,000,000
Transaction, reorganization, and separation	20,000,000	12,000,000	14,000,000	36,000,000
Depreciation, depletion and amortization			1,707,000,000	1,995,000,000
Asset retirement obligation accretion	30,000,000	40,000,000	103,000,000	116,000,000
Impairments	0	836,000,000	8,000,000	1,009,000,000
Financing costs, net	101,000,000	102,000,000	300,000,000	311,000,000
Total operating expenses	1,482,000,000	2,343,000,000	4,197,000,000	5,471,000,000
NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	93,000,000	(905,000,000)	640,000,000	(1,568,000,000)
Current income tax provision	99,000,000	150,000,000	413,000,000	284,000,000
Deferred income tax benefit	(111,000,000)	(529,000,000)	(758,000,000)	(755,000,000)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	105,000,000	(526,000,000)	985,000,000	(1,097,000,000)
Net loss from discontinued operations, net of tax	0	(33,000,000)	0	(33,000,000)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	105,000,000	(559,000,000)	985,000,000	(1,130,000,000)
Net income attributable to noncontrolling interest	42,000,000	48,000,000	137,000,000	93,000,000
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	63,000,000	(607,000,000)	848,000,000	(1,223,000,000)
Net income (loss) from continuing operations attributable to common shareholders	63,000,000	(574,000,000)	848,000,000	(1,190,000,000)
Net loss from discontinued operations	0	(33,000,000)	0	(33,000,000)
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$ 63,000,000	$ (607,000,000)	$ 848,000,000	$ (1,223,000,000)
NET INCOME (LOSS) PER COMMON SHARE:
Basic net income (loss) from continuing operations per share (in USD per share)	$ 0.16	$ (1.51)	$ 2.23	$ (3.14)
Basic net loss from discontinued operations per share (in USD per share)	0	(0.09)	0	(0.08)
Basic net income (loss) per share (in USD per share)	0.16	(1.60)	2.23	(3.22)
DILUTED NET INCOME (LOSS) PER COMMON SHARE:
Diluted net income (loss) from continuing operations per share (in USD per share)	0.16	(1.51)	2.22	(3.14)
Diluted net loss from discontinued operations per share (in USD per share)	0	(0.09)	0	(0.08)
Diluted net income (loss) per share (in USD per share)	$ 0.16	$ (1.60)	$ 2.22	$ (3.22)
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic (in shares)	381	380	381	379
Diluted (in shares)	383	380	383	379
DIVIDENDS DECLARED PER COMMON SHARE (in USD per share)	$ 0.25	$ 0.25	$ 0.75	$ 0.75
Oil and gas property and equipment
OPERATING EXPENSES:
Depreciation, depletion and amortization	$ 524,000,000	$ 610,000,000	$ 1,598,000,000	$ 1,875,000,000
Other assets
OPERATING EXPENSES:
Depreciation, depletion and amortization	35,000,000	38,000,000	109,000,000	120,000,000
Oil revenues
REVENUES AND OTHER:
Oil and Gas Production Revenues	1,070,000,000	1,117,000,000	3,292,000,000	3,057,000,000
Gas revenues
REVENUES AND OTHER:
Oil and Gas Production Revenues	238,000,000	263,000,000	726,000,000	695,000,000
Natural gas liquids revenues
REVENUES AND OTHER:
Oil and Gas Production Revenues	$ 81,000,000	$ 59,000,000	$ 229,000,000	$ 160,000,000

STATEMENT OF CONSOLIDATED COMPR

STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Statement of Comprehensive Income [Abstract]
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	$ 105	$ (559)	$ 985	$ (1,130)
OTHER COMPREHENSIVE INCOME:
Currency translation adjustment	109	0	109	0
COMPREHENSIVE INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	214	(559)	1,094	(1,130)
Comprehensive income attributable to noncontrolling interest	42	48	137	93
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$ 172	$ (607)	$ 957	$ (1,223)

STATEMENT OF CONSOLIDATED CASH

STATEMENT OF CONSOLIDATED CASH FLOWS (Unaudited) - USD ($)	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) including noncontrolling interest	$ 985,000,000	$ (1,130,000,000)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Loss from discontinued operations	0	33,000,000
Unrealized derivative instrument losses, net	42,000,000	0
Gain on divestitures	(616,000,000)	(21,000,000)
Exploratory dry hole expense and unproved leasehold impairments	350,000,000	260,000,000
Depreciation, depletion, and amortization	1,707,000,000	1,995,000,000
Asset retirement obligation accretion	103,000,000	116,000,000
Impairments	8,000,000	1,009,000,000
Deferred income tax benefit	(758,000,000)	(755,000,000)
Other	167,000,000	126,000,000
Changes in operating assets and liabilities:
Receivables	(70,000,000)	192,000,000
Inventories	17,000,000	(2,000,000)
Drilling advances	(72,000,000)	(36,000,000)
Deferred charges and other	(60,000,000)	40,000,000
Accounts payable	2,000,000	(93,000,000)
Accrued expenses	(65,000,000)	(67,000,000)
Deferred credits and noncurrent liabilities	20,000,000	(33,000,000)
NET CASH PROVIDED BY OPERATING ACTIVITIES	1,760,000,000	1,634,000,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(1,471,000,000)	(1,281,000,000)
Leasehold and property acquisitions	(142,000,000)	(169,000,000)
Additions to gas gathering, transmission, and processing facilities	(384,000,000)	(33,000,000)
Proceeds from sale of Canadian assets, net of cash divested	661,000,000	0
Proceeds from sale of oil and gas properties	743,000,000	74,000,000
Other, net	(30,000,000)	47,000,000
NET CASH USED IN INVESTING ACTIVITIES	(623,000,000)	(1,362,000,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments on fixed-rate debt	(70,000,000)	(1,000,000)
Distributions to noncontrolling interest	(212,000,000)	(215,000,000)
Dividends paid	(285,000,000)	(284,000,000)
Other	(5,000,000)	(9,000,000)
NET CASH USED IN FINANCING ACTIVITIES	(572,000,000)	(509,000,000)
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS, AND RESTRICTED CASH	565,000,000	(237,000,000)
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF YEAR	1,377,000,000	1,467,000,000
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD	1,942,000,000	1,230,000,000
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest	341,000,000	345,000,000
Income taxes paid, net of refunds	$ 315,000,000	$ 256,000,000

CONSOLIDATED BALANCE SHEET (Una

CONSOLIDATED BALANCE SHEET (Unaudited) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents	$ 1,846	$ 1,377
Restricted cash	96	0
Receivables, net of allowance	1,145	1,128
Inventories	396	476
Drilling advances	151	81
Prepaid assets and other	135	179
Total current assets	3,769	3,241
Oil and gas, on the basis of successful efforts accounting:
Proved properties	38,569	42,693
Unproved properties and properties under development	1,810	1,969
Gathering, transmission, and processing facilities	1,363	976
Other	1,012	1,111
Property and equipment, gross	42,754	46,749
Less: Accumulated depreciation, depletion, and amortization	(25,099)	(27,882)
Property and equipment, net	17,655	18,867
OTHER ASSETS:
Deferred charges and other	411	411
Total assets	21,835	22,519
CURRENT LIABILITIES:
Accounts payable	583	585
Current debt	550	0
Other current liabilities (Note 5)	1,332	1,258
Total current liabilities	2,465	1,843
LONG-TERM DEBT	7,933	8,544
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	948	1,710
Asset retirement obligation	1,831	2,432
Other	281	311
Total deferred credits and other noncurrent liabilities	3,060	4,453
COMMITMENTS AND CONTINGENCIES (Note 9)
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 414,108,944 and 412,612,102 shares issued, respectively	259	258
Paid-in capital	12,186	12,364
Accumulated deficit	(2,544)	(3,385)
Treasury stock, at cost, 33,171,015 and 33,172,426 shares, respectively	(2,887)	(2,887)
Accumulated other comprehensive loss	(3)	(112)
APACHE SHAREHOLDERS’ EQUITY	7,011	6,238
Noncontrolling interest	1,366	1,441
TOTAL EQUITY	8,377	7,679
TOTAL LIABILITIES AND EQUITY	$ 21,835	$ 22,519

CONSOLIDATED BALANCE SHEET (Un6

CONSOLIDATED BALANCE SHEET (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Common stock, par value (in USD per share)	$ 0.625	$ 0.625
Common stock, shares authorized	860,000,000	860,000,000
Common stock, shares issued	414,108,944	412,612,102
Treasury stock, shares	33,171,015	33,172,426

STATEMENT OF CONSOLIDATED CHANG

STATEMENT OF CONSOLIDATED CHANGES IN EQUITY (Unaudited) - USD ($) $ in Millions	Total	Common Stock	Paid-In Capital	Accumulated Deficit	Treasury Stock	Accumulated Other Comprehensive Loss	APACHE SHAREHOLDERS’ EQUITY	Noncontrolling Interest
Beginning Balance at Dec. 31, 2015	$ 9,490	$ 257	$ 12,619	$ (1,980)	$ (2,889)	$ (119)	$ 7,888	$ 1,602
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(1,130)			(1,223)			(1,223)	93
Distributions to noncontrolling interest	(215)							(215)
Common dividends ($0.75 per share)	(284)		(284)				(284)
Other	88	1	86		1		88
Ending Balance at Sep. 30, 2016	7,949	258	12,421	(3,203)	(2,888)	(119)	6,469	1,480
Beginning Balance at Dec. 31, 2016	7,679	258	12,364	(3,385)	(2,887)	(112)	6,238	1,441
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	985			848			848	137
Distributions to noncontrolling interest	(212)							(212)
Common dividends ($0.75 per share)	(286)		(286)				(286)
Other	211	1	108	(7)		109	211
Ending Balance at Sep. 30, 2017	$ 8,377	$ 259	$ 12,186	$ (2,544)	$ (2,887)	$ (3)	$ 7,011	$ 1,366

STATEMENT OF CONSOLIDATED CHAN8

STATEMENT OF CONSOLIDATED CHANGES IN EQUITY (Unaudited) (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Statement of Stockholders' Equity [Abstract]
Common stock, dividends (USD per share)	$ 0.25	$ 0.25	$ 0.75	$ 0.75

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	These consolidated financial statements have been prepared by Apache Corporation (Apache or the Company) without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). They reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the results for the interim periods, on a basis consistent with the annual audited financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. This Quarterly Report on Form 10-Q should be read along with Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 , which contains a summary of the Company’s significant accounting policies and other disclosures. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES As of September 30, 2017 , Apache’s significant accounting policies are consistent with those discussed in Note 1—Summary of Significant Accounting Policies of its consolidated financial statements contained in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 , with the exception of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) 2016-09, “Improvements to Employee Share-Based Payment Accounting” and ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash” (see “Recently Adopted Accounting Pronouncements” in this Note 1 below). Use of Estimates The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the 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. Significant estimates with regard to these financial statements include the fair value determination of acquired assets and liabilities, the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom, the assessment of asset retirement obligations, the estimates of fair value for long-lived assets and goodwill, and the estimate of income taxes. Actual results could differ from those estimates. Fair Value Measurements Certain assets and liabilities are reported at fair value on a recurring basis in Apache’s consolidated balance sheet. Accounting Standards Codification (ASC) 820-10-35, “Fair Value Measurement” (ASC 820), 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). Apache also uses fair value measurements on a nonrecurring basis when certain qualitative assessments of its assets indicate a potential impairment. The Company recorded no asset impairments in connection with fair value assessments in the third quarter of 2017 . For the nine -month period ended September 30, 2017 , the Company recorded asset impairments totaling $8 million in connection with fair value assessments. In 2016, the U.K. government enacted Finance Bill 2016, providing tax relief to exploration and production (E&P) companies operating in the U.K. North Sea. Under the enacted legislation, the U.K. Petroleum Revenue Tax (PRT) rate was reduced to zero from the previously enacted 35 percent rate in effect from January 1, 2016. PRT expense ceased prospectively from that date. During the first quarter of 2017, the Company fully impaired the aggregate remaining value of the recoverable PRT decommissioning asset of $8 million that would have been realized from future abandonment activities. The recoverable value of the PRT decommissioning asset was estimated using the income approach. The expected future cash flows used in the determination were based on anticipated spending and timing of planned future abandonment activities for applicable fields, considering all available information at the date of review. Apache has classified this fair value measurement as Level 3 in the fair value hierarchy. For the quarter ended September 30, 2016 , the Company recorded asset impairments totaling $836 million in connection with fair value assessments including $355 million for proved oil and gas properties in Canada and $481 million for the impairment of the recoverable value of the PRT decommissioning asset. For the nine -month period ended September 30, 2016 , the Company recorded asset impairments totaling $1.0 billion in connection with fair value assessments including $423 million for proved oil and gas properties in the U.S. and Canada, $481 million for the impairment of the recoverable value of the PRT decommissioning asset, and $105 million for the impairment of certain gas gathering, transmission, and processing (GTP) assets, which were written down to their fair values of $175 million . 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 geological and geophysical costs, delay rentals, 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. The reserve base used to calculate the depreciation for capitalized costs of exploratory wells and development costs is the sum of proved developed reserves only. 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. If applicable, the Company utilizes prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured 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 the third quarters and first nine months of 2017 and 2016 : Quarter Ended September 30, Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Oil and Gas Property: Proved $ — $ 355 $ — $ 423 Unproved 160 114 214 222 Proved properties impaired during the second and third quarters of 2016 had aggregate fair values of $143 million and $163 million , respectively. On the statement of consolidated operations, unproved impairments are recorded in exploration expense, and proved impairments are recorded in impairments. Recently Adopted Accounting Pronouncements Stock Compensation In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting.” ASU 2016-09 simplifies several aspects of accounting for share-based payment transactions including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The guidance was effective for fiscal years beginning after December 15, 2016. The Company adopted ASU 2016-09 effective January 1, 2017. Upon adoption, the Company elected to account for forfeitures as they occur rather than estimate expected forfeitures using a modified retrospective transition method. As a result of this election, the Company recorded a cumulative-effect adjustment of $11 million , representing an increase in accumulated deficit, with the offset to paid-in capital. During the first quarter of 2017, the Company recorded a $4 million deferred tax asset related to this adjustment, with the offset to accumulated deficit. ASU 2016-09 requires excess tax benefits and deficiencies to be recognized prospectively as part of the provision for income taxes rather than paid-in capital. The adoption did not have a material impact on the Company’s accounting of provision for income taxes. ASU 2016-09 also requires excess tax benefits to be presented as a component of operating cash flows rather than financing cash flows. The Company has adopted this requirement prospectively and accordingly, prior periods have not been adjusted. Excess tax benefits were not material for all periods presented. Additionally, ASU 2016-09 requires that employee taxes paid when an employer withholds shares for tax-withholding purposes be reported as financing activities in the consolidated statements of cash flows, which is how the Company has historically classified these amounts. Restricted Cash In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash.” ASU 2016-18 requires amounts generally described as restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the total beginning and ending amounts for the periods shown on the statement of cash flows. The guidance is effective for annual and interim periods beginning after December 15, 2017, and is required to be adopted using a retrospective approach, with early adoption permitted. The Company adopted ASU 2016-18 in the third quarter of 2017. Other than the change in presentation within the statement of consolidated cash flows, the adoption of ASU 2016-18 did not have an impact on the Company’s consolidated financial statements. The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the consolidated balance sheet to the amounts shown in the statement of consolidated cash flows: September 30, 2017 December 31, 2016 (In millions) Cash and cash equivalents $ 1,846 $ 1,377 Restricted cash 96 — Total cash, cash equivalents, and restricted cash shown in the statement of consolidated cash flows $ 1,942 $ 1,377 For information regarding the restricted cash balance, please refer to Note 2—Acquisitions and Divestitures. New Pronouncements Issued But Not Yet Adopted In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, and the Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. Early adoption is permitted; however, the Company does not intend to early adopt. As part of the assessment to date, the Company has formed an implementation work team and is continuing to evaluate contracts to determine the impact this ASU will have on its consolidated financial statements. At this time, the Company cannot reasonably estimate the financial impact this will have on its consolidated financial statements; however, the Company believes adoption and implementation of this ASU will significantly impact its balance sheet, resulting in an increase in both assets and liabilities relating to its leasing activities. In May 2014, the FASB and the International Accounting Standards Board (IASB) issued a joint revenue recognition standard, ASU 2014-09, “Revenue from Contracts with Customers (Topic 606).” The new standard removes inconsistencies in existing standards, changes the way companies recognize revenue from contracts with customers, and increases disclosure requirements. The codification was amended through additional ASUs and, as amended, 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. The guidance is 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 continues to make progress on evaluating the accounting implications of this ASU and its assessment of contracts with customers is largely complete. Based on the Company’s evaluation to date, it does not expect the adoption of this ASU to have a material impact on net earnings, however, the Company is analyzing whether the classification of certain items in revenue and expense will be impacted. The Company continues to evaluate the disclosure requirements, develop accounting policies, and assess changes to the relevant business processes and the control activities within them as a result of the provisions of this ASU. The Company will adopt the new standard on January 1, 2018, utilizing the modified retrospective approach.

ACQUISITIONS AND DIVESTITURES

ACQUISITIONS AND DIVESTITURES	9 Months Ended
	Sep. 30, 2017
Business Combinations [Abstract]
ACQUISITIONS AND DIVESTITURES	ACQUISITIONS AND DIVESTITURES 2017 Activity Canada Divestitures During the third quarter, Apache announced the sale of its subsidiary Apache Canada Ltd. (ACL) and complete exit of its Canadian operations. On June 30, 2017, Apache completed the sale of its Canadian assets at Midale and House Mountain, located in Saskatchewan and Alberta, for aggregate cash proceeds of approximately $228 million . The Company recognized a $52 million loss during the second quarter of 2017 in association with this sale. In August of 2017, Apache completed the sale of its remaining Canadian operations for aggregate cash proceeds of approximately $478 million . The Company recognized a $74 million gain upon closing of these transactions in the third quarter of 2017. The Company has classified $96 million of proceeds as “Restricted cash” on the Company’s consolidated balance sheet, pending the Alberta Energy Regulator’s clearance of the transfer of Provost area licenses from ACL to the buyer. A summary of the assets and liabilities at closing of the August transactions is detailed below: (In millions) ASSETS Current assets $ 110 Property, plant & equipment 1,132 Total Assets $ 1,242 LIABILITIES Current liabilities, excluding asset retirement obligation $ 120 Asset retirement obligation 780 Other long-term liabilities 46 Total Liabilities $ 946 The net carrying value of the assets disposed included a currency translation loss of $109 million , which was recorded in “Accumulated Other Comprehensive Loss” on the Company’s consolidated balance sheet at December 31, 2016. The currency translation loss was recognized as a reduction of the net gain on sale during the third quarter of 2017 upon closing of the transactions. Apache’s Canadian operations recorded pretax losses of $12 million and $141 million for the third quarter and first nine months of 2017 , respectively, compared to pretax losses of $483 million and $644 million , respectively, for the comparable periods in 2016 . U.S. Divestitures During the first nine months of 2017, Apache completed the sale of certain non-core assets, primarily leasehold acreage in the Permian and Midcontinent/Gulf Coast regions, in multiple transactions for cash proceeds of $783 million , subject to customary closing adjustments. A refundable deposit of $40 million was received in the fourth quarter of 2016 in connection with certain of these transactions. The Company recognized gains of approximately $594 million during the first nine months of 2017 in connection with these transactions. North Sea GTP Divestiture During the fourth quarter of 2016, Apache entered into an agreement to sell its 30.28 percent interest in the Scottish Area Gas Evacuation system (SAGE) and its 60.56 percent interest in the Beryl pipeline in the North Sea to Ancala Midstream Acquisitions Limited (Ancala). The transaction is subject to regulatory and third-party approvals, which are ongoing in 2017. The Company received a refundable deposit in connection with this transaction, which is recorded in “Other current liabilities” on the consolidated balance sheet. The refundable deposit was $149 million as of September 30, 2017 . Leasehold and Property Acquisitions During the third quarter and first nine months of 2017 , Apache purchased $75 million and $142 million , respectively, of leasehold and property acquisitions primarily in its North America onshore regions. 2016 Activity Leasehold and Property Acquisitions During the third quarter and first nine months of 2016 , Apache purchased $51 million and $169 million , respectively, of leasehold and property acquisitions primarily in its North America onshore regions and Egypt. Discontinued Operations Apache sold its operations in Argentina and Australia in 2014 and 2015, respectively. The results of operations related to the Argentina and Australia dispositions and the losses on disposals were classified as discontinued operations in the Company’s financial statements. During 2016, the Company incurred additional losses on these dispositions. The components of the Company’s loss from discontinued operations were as follows: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Loss from Australia divestiture $ — $ (23 ) $ — $ (23 ) Loss from Argentina divestiture — (10 ) — (10 ) Loss from discontinued operations, net of tax $ — $ (33 ) $ — $ (33 ) Transaction, Reorganization, and Separation During the third quarter and first nine months of 2017 , Apache recorded $20 million and $14 million , respectively, in expense related to asset divestitures in the U.S. and Canada and employee separation. During the third quarter and first nine months of 2016 , Apache recorded $12 million and $36 million , respectively, in expense related to various asset divestitures, company reorganization, and employee separation.

DERIVATIVE INSTRUMENTS AND HEDG

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	9 Months Ended
	Sep. 30, 2017
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. The Company utilizes various types of derivative financial instruments to manage fluctuations in cash flows resulting from changes in commodity prices. The Company’s derivatives are not designated as cash flow hedges, therefore, changes in fair value are recognized currently in earnings. Counterparty Risk The use of derivative instruments exposes the Company to credit loss in the event of nonperformance by the counterparty. To reduce the concentration of exposure to any individual counterparty, Apache utilizes a diversified group of investment-grade rated counterparties, primarily financial institutions, for its derivative transactions. As of September 30, 2017 , Apache had derivative positions with 14 counterparties. The Company monitors counterparty creditworthiness on an ongoing basis; however, it cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, the Company may be limited in its ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, Apache may not realize the benefit of some of its derivative instruments resulting from lower commodity prices. Derivative Instruments As of September 30, 2017 , Apache had the following open crude oil derivative positions: Put Options (1)(2) Production Period Settlement Index Mbbls Weighted Average Strike Price October—December 2017 NYMEX WTI 8,464 $50.00 October—December 2017 Dated Brent 7,636 $51.00 (1) The remaining unamortized premium paid as of September 30, 2017 , was $50 million . (2) Subsequent to September 30, 2017 , Apache entered into put option contracts settling against Dated Brent totaling 3,650 Mbbls with a strike price of $50 for the calendar year 2018. Fixed-Price Swaps Collars (3) Call Options (4) Production Period Settlement Index Mbbls Weighted Average Fixed Price Mbbls Weighted Average Floor Price Weighted Average Ceiling Price Mbbls Strike Price January—June 2018 NYMEX WTI 2,715 $51.23 2,715 $45.00 $56.45 — — January—June 2018 Dated Brent 2,172 $54.57 2,172 $50.00 $58.77 — — January—December 2018 NYMEX WTI — — 6,023 $45.00 $57.02 6,023 $60.00 (3) Subsequent to September 30, 2017 , Apache entered into crude oil contracts settling against NYMEX WTI totaling 730 Mbbls with a floor and ceiling of $45.00 and $56.90 , respectively, for the calendar year 2018. (4) The remaining unamortized premium paid as of September 30, 2017 , was $9 million . As of September 30, 2017 , Apache had the following open natural gas derivative positions: Fixed-Price Swaps (1) Production Period Settlement Index MMBtu (in 000’s) Weighted Average Fixed Price October—December 2017 NYMEX Henry Hub 4,370 $3.32 January—March 2018 NYMEX Henry Hub 13,500 $3.39 January—June 2018 NYMEX Henry Hub 22,625 $3.17 April—June 2018 NYMEX Henry Hub 16,835 $2.92 July—December 2018 NYMEX Henry Hub 18,400 $2.97 (1) Subsequent to September 30, 2017 , Apache entered into fixed-price natural gas swaps settling against NYMEX Henry Hub totaling 15,180,000 MMBtu with a weighted average fixed-price of $2.95 for the second half of 2018. As of September 30, 2017 , Apache had the following open natural gas financial basis swap contracts: Production Period Settlement Index MMBtu (in 000’s) Weighted Average Price Differential January—March 2018 NYMEX Henry Hub/Waha 9,450 $(0.43) July—December 2018 NYMEX Henry Hub/Waha 33,120 $(0.53) October—December 2018 NYMEX Henry Hub/Waha 1,380 $(0.51) January—March 2019 NYMEX Henry Hub/Waha 1,350 $(0.54) January—June 2019 NYMEX Henry Hub/Waha 32,580 $(0.53) January—December 2019 NYMEX Henry Hub/Waha 14,600 $(0.45) Fair Value Measurements Apache’s commodity derivative instruments consist of variable-to-fixed price commodity swaps, options, and collars. The fair values of the Company’s derivatives are not actively quoted in the open market. The Company uses a market approach to estimate the fair values of its derivative instruments on a recurring basis, utilizing commodity futures pricing for the underlying commodities provided by a reputable third party, a Level 2 fair value measurement. The following table presents the Company’s derivative assets and liabilities measured at fair value on a recurring basis: Fair Value Measurements Using Quoted Price in Active Markets (Level 1) Significant Other Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value Netting (1) Carrying Amount (In millions) September 30, 2017 Assets: Commodity Derivative Instruments $ — $ 24 $ — $ 24 $ (7 ) $ 17 Liabilities: Commodity Derivative Instruments — 7 — 7 (7 ) — December 31, 2016 Assets: Commodity Derivative Instruments $ — $ — $ — $ — $ — $ — Liabilities: Commodity Derivative Instruments — — — — — — (1) The derivative fair values are based on analysis of each contract on a gross basis, excluding the impact of netting agreements with counterparties. All derivative instruments are reflected as either assets or liabilities at fair value in the consolidated balance sheet. These fair values are recorded by netting asset and liability positions where counterparty master netting arrangements contain provisions for net settlement. The carrying value of the Company’s derivative assets and liabilities and their locations on the consolidated balance sheet are as follows: September 30, 2017 December 31, 2016 (In millions) Current Assets: Prepaid assets and other $ 13 $ — Other Assets: Deferred charges and other 4 — Total Assets $ 17 $ — 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: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Realized gain (loss): Derivative settlements, realized gain $ 23 $ — $ 23 $ — Amortization of put premium, realized loss (50 ) — (50 ) — Unrealized loss (83 ) — (42 ) — Derivative instrument losses, net $ (110 ) $ — $ (69 ) $ — Unrealized gains and losses for derivative activity recorded in the statement of consolidated operations is reflected in the statement of consolidated cash flows separately as a component of “Unrealized derivative instrument losses, net” in “Adjustments to reconcile net income (loss) to net cash provided by operating activities.”

CAPITALIZED EXPLORATORY WELL CO

CAPITALIZED EXPLORATORY WELL COSTS	9 Months Ended
	Sep. 30, 2017
Extractive Industries [Abstract]
CAPITALIZED EXPLORATORY WELL COSTS	CAPITALIZED EXPLORATORY WELL COSTS The Company’s capitalized exploratory well costs were $369 million and $264 million at September 30, 2017 and December 31, 2016 , respectively. The increase is primarily attributable to additional drilling activities in the U.S. during the period, partially offset by successful transfers and dry hole write-offs. No suspended exploratory well costs previously capitalized for greater than one year at December 31, 2016 were charged to dry hole expense during the nine months ended September 30, 2017 . 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.

OTHER CURRENT LIABILITIES

OTHER CURRENT LIABILITIES	9 Months Ended
	Sep. 30, 2017
Payables and Accruals [Abstract]
OTHER CURRENT LIABILITIES	OTHER CURRENT LIABILITIES The following table provides detail of the Company’s other current liabilities as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 (In millions) Accrued operating expenses $ 73 $ 110 Accrued exploration and development 691 463 Accrued compensation and benefits 99 201 Accrued interest 108 145 Accrued income taxes 68 22 Current asset retirement obligation 35 66 Refundable deposits 149 174 Other 109 77 Total other current liabilities $ 1,332 $ 1,258

ASSET RETIREMENT OBLIGATION

ASSET RETIREMENT OBLIGATION	9 Months Ended
	Sep. 30, 2017
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 nine -month period ended September 30, 2017 : (In millions) Asset retirement obligation at December 31, 2016 $ 2,498 Liabilities incurred 39 Liabilities divested (810 ) Liabilities settled (30 ) Accretion expense 103 Revisions in estimated liabilities 66 Asset retirement obligation at September 30, 2017 1,866 Less current portion 35 Asset retirement obligation, long-term $ 1,831

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The Company estimates its annual effective income tax rate for continuing operations in recording its quarterly provision for income taxes in the various jurisdictions in which the Company operates. Non-cash impairments of the carrying value of the Company’s oil and gas properties, gains and losses on the sale of assets, statutory tax rate changes, and other significant or unusual items are recognized as discrete items in the quarter in which they occur. In August 2017, Apache completed the sale of ACL. For more information regarding this transaction, please refer to Note 2—Acquisitions and Divestitures. As a result of this transaction, Apache recorded a deferred tax asset associated with its realizable capital loss on the sale of ACL, and a decrease in the Company’s deferred tax liability associated with its investment in foreign subsidiaries. In the third and second quarters of 2017, the Company recorded a $2 million deferred income tax expense and a $674 million deferred income tax benefit, respectively, in connection with these transactions. Apache’s third quarter of 2017 effective income tax rate was primarily impacted by gains on the sale of oil and gas properties and a $30 million current tax benefit associated with U.S. federal income tax credits. On September 15, 2016, U.K. Finance Act 2016 received Royal Assent. Under the enacted legislation, the corporate income tax rate on North Sea oil and gas profits was reduced from 50 percent to 40 percent effective January 1, 2016. As a result of the enacted legislation, in the third quarter of 2016 the Company recorded a deferred tax benefit of $235 million related to the remeasurement of the Company’s December 31, 2015 U.K. deferred income tax liability. Apache’s 2017 year-to-date effective income tax rate is primarily impacted by the decrease in deferred taxes associated with its investments in foreign subsidiaries, gains on the sale of oil and gas properties, non-cash impairments of the Company’s PRT decommissioning asset, and the current tax benefit associated with U.S. federal income tax credits. Apache’s 2016 year-to-date effective income tax rate was primarily impacted by non-cash impairments of the carrying value of the Company’s oil and gas properties, non-cash impairments of the Company’s PRT decommissioning asset, the impact of the change in U.K. statutory income tax rate, and an increase in the amount of valuation allowances on U.S. and Canadian deferred tax assets. Apache and its subsidiaries are subject to U.S. federal income tax as well as income or capital taxes in various state and foreign jurisdictions. The Company’s tax reserves are related to tax years that may be subject to examination by the relevant taxing authority. In April 2017, the Internal Revenue Service (IRS) began their audit of the Company’s 2014 income tax year. The Company is also under audit in various states and in most of the Company’s foreign jurisdictions as part of its normal course of business.

DEBT AND FINANCING COSTS

DEBT AND FINANCING COSTS	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
DEBT AND FINANCING COSTS	DEBT AND FINANCING COSTS The following table presents the carrying amounts and estimated fair values of the Company’s outstanding debt as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Commercial paper and committed bank facilities $ — $ — $ — $ — Notes and debentures 8,483 9,094 8,544 9,183 Total Debt $ 8,483 $ 9,094 $ 8,544 $ 9,183 The Company’s debt is recorded at the carrying amount, net of related unamortized discount and debt issuance costs, on its consolidated balance sheet. When recorded, the carrying amount of the Company’s commercial paper, committed bank facilities, and uncommitted bank lines approximates 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 notes and debentures using estimates provided by an independent investment financial data services firm (a Level 2 fair value measurement). The following table presents the carrying value of the Company’s debt as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 (In millions) Debt before unamortized discount and debt issuance costs $ 8,580 $ 8,650 Unamortized discount (48 ) (50 ) Debt issuance costs (49 ) (56 ) Total debt 8,483 8,544 Current maturities (550 ) — Long-term debt $ 7,933 $ 8,544 As of September 30, 2017 , current debt included $150 million of 7.0% senior notes due February 1, 2018 and $400 million of 6.9% senior notes due September 15, 2018. As of September 30, 2017 , the Company had a revolving credit facility that 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 $3.5 billion commercial paper program. The commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of September 30, 2017 , the Company had no commercial paper or borrowings under committed bank facilities or uncommitted bank lines outstanding. As of September 30, 2017 , the Company had a letter of credit facility, which provides for £900 million in commitments and rights to increase commitments to £1.075 billion . This facility matures in February 2020 . The facility is available for letters of credit and loans to cash collateralize letters of credit or obligations to provide letters of credit, in each case, to the extent letters of credit are unavailable under the facility. As of September 30, 2017 , three letters of credit aggregating approximately £147.5 million and no borrowings were outstanding under this facility. In November 2016, the Company initiated a program to purchase in the open market up to $250 million in aggregate principal amount of senior notes issued under its indentures. In the fourth quarter of 2016, the Company purchased and canceled $181 million aggregate principal amount of its senior notes through open market repurchases for $182 million in cash, including accrued interest and $0.5 million of premium. In January 2017, the Company purchased and canceled an additional $69 million aggregate principal amount of senior notes for $71 million in cash, including accrued interest and $1 million of premium, which completed the open market repurchase program. These repurchases resulted in a $1 million net loss on extinguishment of debt, which is included in “Financing costs, net” in the Company’s consolidated statement of operations. The net loss includes an acceleration of related discount and deferred financing costs. In August 2017, the Company assumed the obligations of Apache Finance Canada Corporation (AFCC) in respect of $300 million 7.75% notes due in 2029 which AFCC issued and the Company guaranteed pursuant to the governing indenture. The assumption was permitted by the indenture and effected pursuant to a supplemental indenture thereto. As a result of the assumption, the Company is the obligor under the notes and indenture, and AFCC is released from its obligations thereunder. The $300 million 7.75% notes historically have been included in the Company’s long-term debt; accordingly, the assumption did not change the Company’s long-term debt or total debt. Financing Costs, Net The following table presents the components of Apache’s financing costs, net: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Interest expense $ 113 $ 116 $ 344 $ 348 Amortization of deferred loan costs 3 2 7 5 Capitalized interest (12 ) (13 ) (39 ) (36 ) Loss on extinguishment of debt — — 1 — Interest income (3 ) (3 ) (13 ) (6 ) Financing costs, net $ 101 $ 102 $ 300 $ 311

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2017
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. As of September 30, 2017 , the Company has an accrued liability of approximately $37 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. For additional information on each of the Legal Matters described below, please see Note 10—Commitments and Contingencies to the consolidated financial statements contained in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . Argentine Environmental Claims and Argentina Tariff No material change in the status of the YPF Sociedad Anónima and Pioneer Natural Resources Company indemnities matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . Louisiana Restoration As more fully described in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 , numerous surface owners have filed claims or sent demand letters to various oil and gas companies, including Apache, claiming that, under either express or implied lease terms or Louisiana law, the companies are liable for damage measured by the cost of restoration of leased premises to their original condition as well as damages for contamination and cleanup. 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 alleged 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. The defendants removed the case from state court to federal court and, on February 13, 2015, the federal court entered judgment in favor of defendants dismissing all of plaintiff’s claims with prejudice. Plaintiff appealed the lower court’s dismissal to the 5 th Circuit Court of Appeals and additionally challenged the defendants’ right to remove the case to federal court. On March 3, 2017, the 5 th Circuit Court of Appeals affirmed the propriety of federal jurisdiction based in part on Apache’s argument that plaintiff’s state-based claims required a resolution of substantial questions of federal law and also affirmed the dismissal of the action. The Plaintiff filed a Petition for a Writ of Certiorari with the United States Supreme Court. On October 30, 2017, the United States Supreme Court denied review and declined to consider the plaintiff’s Petition of Certiorari. Starting in November of 2013 and continuing into 2017, several Parishes in Louisiana have pending lawsuits against many oil and gas producers, including Apache. These cases are pending in federal and state courts in Louisiana. In these cases, the Parishes, as plaintiffs, allege that 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. While an adverse judgment against Apache might be possible, Apache intends to vigorously oppose these claims. No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . Apollo Exploration Lawsuit In a fourth amended petition filed on March 21, 2016, in a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation , Cause No. CV50538 in the 385 th Judicial District Court, Midland County, Texas, plaintiffs have reduced their alleged damages to approximately $500 million (having previously claimed 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. The Court recently granted two of Apache’s motions for summary judgment further limiting the plaintiffs’ theories and potential damages. Apache believes that plaintiffs’ claims lack merit, and further that plaintiffs’ alleged damages, even as amended, are grossly inflated. Apache will vigorously oppose the claims. No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . Escheat Audits There has been no material change with respect to the review of the books and records of the Company and its subsidiaries and related entities by the State of Delaware, Department of Finance (Unclaimed Property), to determine compliance with the Delaware Escheat Laws, since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . Environmental Matters As of September 30, 2017 , the Company had an undiscounted reserve for environmental remediation of approximately $4 million . The Company is not aware of any environmental claims existing as of September 30, 2017 , that have not been provided for or would otherwise have a material impact on its financial position, results of operations, or liquidity. 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. ACL, a former subsidiary of the Company, previously reported produced water spills in a remote area of the Bellow Field and a hydrogen sulfide and oil emulsion leak in the Zama area. The Company sold ACL in a transaction that was completed in the third quarter of 2017. The Canadian environmental litigation and liabilities remained with ACL and are now the responsibility of the acquirer. In addition to the matters for which the Company has already accrued, on July 17, 2017, in three separate actions, San Mateo County, California, Marin County, California, and the City of Imperial Beach, California, all filed suit individually and on behalf of the people of the state of California against over 30 oil, gas, and coal companies alleging damages as a result of global warming. Plaintiffs seek unspecified damages and abatement under various tort theories. Apache believes that the claims made against it are baseless and intends to vigorously defend these lawsuits. Australian Operations Divestiture Dispute By a Sale and Purchase Agreement dated April 9, 2015 (SPA), the Company and its subsidiaries divested their remaining Australian operations to Viraciti Energy Pty Ltd, which has since been renamed Quadrant Energy Pty Ltd (Quadrant). Closing occurred on June 5, 2015. By letter dated June 6, 2016, Quadrant provided the Company with a placeholder notice of claim under the SPA concerning tax and other issues totaling approximately $200 million in the aggregate. The Company believes that these claims lack merit and intends to vigorously defend against them. Moreover, on September 22, 2017, subsidiaries of the Company filed suit against Quadrant for breaching the SPA and wrongfully withholding tax refunds owed under the SPA. This claim totals approximately $80 million AUD.

CAPITAL STOCK

CAPITAL STOCK	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
CAPITAL STOCK	CAPITAL STOCK Net Income (Loss) per Common Share A reconciliation of the components of basic and diluted net income (loss) per common share for the quarters and nine months ended September 30, 2017 and 2016 , is presented in the table below. For the Quarter Ended September 30, 2017 2016 Income Shares Per Share Loss Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ 63 381 $ 0.16 $ (574 ) 380 $ (1.51 ) Loss from discontinued operations — 381 — (33 ) 380 (0.09 ) Income (loss) attributable to common stock $ 63 381 $ 0.16 $ (607 ) 380 $ (1.60 ) Effect of Dilutive Securities: Stock options and other $ — 2 $ — $ — — $ — Diluted: Income (loss) from continuing operations $ 63 383 $ 0.16 $ (574 ) 380 $ (1.51 ) Loss from discontinued operations — 383 — (33 ) 380 (0.09 ) Income (loss) attributable to common stock $ 63 383 $ 0.16 $ (607 ) 380 $ (1.60 ) For the Nine Months Ended September 30, 2017 2016 Income Shares Per Share Loss Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ 848 381 $ 2.23 $ (1,190 ) 379 $ (3.14 ) Loss from discontinued operations — 381 — (33 ) 379 (0.08 ) Income (loss) attributable to common stock $ 848 381 $ 2.23 $ (1,223 ) 379 $ (3.22 ) Effect of Dilutive Securities: Stock options and other $ — 2 $ (0.01 ) $ — — $ — Diluted: Income (loss) from continuing operations $ 848 383 $ 2.22 $ (1,190 ) 379 $ (3.14 ) Loss from discontinued operations — 383 — (33 ) 379 (0.08 ) Income (loss) attributable to common stock $ 848 383 $ 2.22 $ (1,223 ) 379 $ (3.22 ) The diluted earnings per share calculation excludes options and restricted stock units that were anti-dilutive totaling 8.4 million and 4.7 million for the quarters ended September 30, 2017 and 2016 , respectively, and 7.5 million and 6.5 million for the nine months ended September 30, 2017 and 2016 , respectively. Common Stock Dividends For each of the quarters ended September 30, 2017 , and 2016 , Apache paid $95 million in dividends on its common stock. For the nine months ended September 30, 2017 and 2016 , the Company paid $285 million and $284 million , respectively. 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 negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through September 30, 2017 , had repurchased a total of 32.2 million shares at an average price of $88.96 per share. The Company is not obligated to acquire any specific number of shares and has not purchased any shares during 2017 .

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE LOSS	ACCUMULATED OTHER COMPREHENSIVE LOSS The following table describes changes to the Company’s accumulated other comprehensive loss by component for the nine -month period ended September 30, 2017 : Currency Translation Adjustment Pension and Postretirement Benefit Plan Total (In millions) Accumulated other comprehensive loss at December 31, 2016 $ (109 ) $ (3 ) $ (112 ) Currency translation adjustment divested (1) 109 — 109 Accumulated other comprehensive loss at September 30, 2017 $ — $ (3 ) $ (3 ) (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 loss. This currency translation loss was recognized as a reduction of the net gain on divestiture during the third quarter of 2017 in connection with the Canada divestitures. For more information regarding these divestitures, please refer to Note 2—Acquisitions and Divestitures.

BUSINESS SEGMENT INFORMATION

BUSINESS SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2017
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 September 30, 2017 , the Company had production in three reporting segments: the United States, Egypt, and offshore the United Kingdom in the North Sea (North Sea). Apache also has exploration interests in Suriname that may, over time, result in a reportable discovery and development opportunity. Financial information for each area is presented below: United States Canada (1) Egypt (2) North Sea Other International Total (In millions) For the Quarter Ended September 30, 2017 Oil and Gas Production Revenues $ 550 $ 36 $ 543 $ 260 $ — $ 1,389 Operating Income (Loss) (3) $ (114 ) $ (1 ) $ 226 $ 16 $ (1 ) $ 126 Other Income (Expense): Gain on divestitures, net 296 Derivative instrument losses, net (110 ) General and administrative (98 ) Transaction, reorganization, and separation (20 ) Financing costs, net (101 ) Income Before Income Taxes $ 93 For the Nine Months Ended September 30, 2017 Oil and Gas Production Revenues $ 1,593 $ 231 $ 1,655 $ 768 $ — $ 4,247 Operating Income (Loss) (3) $ (71 ) $ (33 ) $ 740 $ 59 $ (24 ) $ 671 Other Income (Expense): Gain on divestitures, net 616 Derivative instrument losses, net (69 ) Other 43 General and administrative (307 ) Transaction, reorganization, and separation (14 ) Financing costs, net (300 ) Income Before Income Taxes $ 640 Total Assets $ 13,105 $ — $ 4,906 $ 3,770 $ 54 $ 21,835 United States Canada (1) Egypt (2) North Sea Other International Total (In millions) For the Quarter Ended September 30, 2016 Oil and Gas Production Revenues $ 524 $ 87 $ 581 $ 247 $ — $ 1,439 Operating Income (Loss) (4) $ (17 ) $ (466 ) $ 263 $ (455 ) $ (13 ) $ (688 ) Other Income (Expense): Gain on divestitures, net 5 Other (6 ) General and administrative (102 ) Transaction, reorganization, and separation (12 ) Financing costs, net (102 ) Loss From Continuing Operations Before Income Taxes $ (905 ) For the Nine Months Ended September 30, 2016 Oil and Gas Production Revenues $ 1,453 $ 243 $ 1,515 $ 701 $ — $ 3,912 Operating Income (Loss) (4) $ (283 ) $ (586 ) $ 525 $ (557 ) $ (13 ) $ (914 ) Other Income (Expense): Gain on divestitures, net 21 Other (30 ) General and administrative (298 ) Transaction, reorganization, and separation (36 ) Financing costs, net (311 ) Loss From Continuing Operations Before Income Taxes $ (1,568 ) Total Assets $ 12,299 $ 1,630 $ 5,320 $ 3,851 $ 49 $ 23,149 (1) During the third quarter of 2017, Apache completed the sale of its Canadian operations. For more information regarding this divestiture, please refer to Note 2—Acquisitions and Divestitures. (2) Includes a noncontrolling interest in Egypt. (3) Operating income (loss) consists of oil and gas production revenues less lease operating expenses, gathering and transportation costs, taxes other than income, exploration costs, depreciation, depletion, and amortization, asset retirement obligation accretion, and impairments. The operating income (loss) of U.S. includes leasehold impairments totaling $160 million for the third quarter of 2017 . The operating income (loss) of U.S., Canada, and North Sea includes leasehold and other asset impairments totaling $212 million , $2 million , and $8 million , respectively, for the first nine months of 2017 . (4) The operating income (loss) of U.S., Canada, and North Sea includes leasehold, property, and other asset impairments totaling $46 million , $423 million , and $481 million , respectively, for the third quarter of 2016 . The operating income (loss) of U.S., Canada, and North Sea includes leasehold, property, and other asset impairments totaling $212 million , $433 million , and $586 million , respectively, for the first nine months of 2016 .

SUMMARY OF SIGNIFICANT ACCOUN21

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the 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. Significant estimates with regard to these financial statements include the fair value determination of acquired assets and liabilities, the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom, the assessment of asset retirement obligations, the estimates of fair value for long-lived assets and goodwill, and the estimate of income taxes. Actual results could differ from those estimates.
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. Accounting Standards Codification (ASC) 820-10-35, “Fair Value Measurement” (ASC 820), 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). Apache also uses fair value measurements on a nonrecurring basis when certain qualitative assessments of its assets indicate a potential impairment. The Company recorded no asset impairments in connection with fair value assessments in the third quarter of 2017 . For the nine -month period ended September 30, 2017 , the Company recorded asset impairments totaling $8 million in connection with fair value assessments. In 2016, the U.K. government enacted Finance Bill 2016, providing tax relief to exploration and production (E&P) companies operating in the U.K. North Sea. Under the enacted legislation, the U.K. Petroleum Revenue Tax (PRT) rate was reduced to zero from the previously enacted 35 percent rate in effect from January 1, 2016. PRT expense ceased prospectively from that date. During the first quarter of 2017, the Company fully impaired the aggregate remaining value of the recoverable PRT decommissioning asset of $8 million that would have been realized from future abandonment activities. The recoverable value of the PRT decommissioning asset was estimated using the income approach. The expected future cash flows used in the determination were based on anticipated spending and timing of planned future abandonment activities for applicable fields, considering all available information at the date of review. Apache has classified this fair value measurement as Level 3 in the fair value hierarchy.
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 geological and geophysical costs, delay rentals, 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. The reserve base used to calculate the depreciation for capitalized costs of exploratory wells and development costs is the sum of proved developed reserves only. 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. If applicable, the Company utilizes prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured 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 the third quarters and first nine months of 2017 and 2016 : Quarter Ended September 30, Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Oil and Gas Property: Proved $ — $ 355 $ — $ 423 Unproved 160 114 214 222 Proved properties impaired during the second and third quarters of 2016 had aggregate fair values of $143 million and $163 million , respectively. On the statement of consolidated operations, unproved impairments are recorded in exploration expense, and proved impairments are recorded in impairments.
Recently Adopted Accounting Pronouncements and New Pronouncements Issued But Not Yet Adopted	Recently Adopted Accounting Pronouncements Stock Compensation In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting.” ASU 2016-09 simplifies several aspects of accounting for share-based payment transactions including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The guidance was effective for fiscal years beginning after December 15, 2016. The Company adopted ASU 2016-09 effective January 1, 2017. Upon adoption, the Company elected to account for forfeitures as they occur rather than estimate expected forfeitures using a modified retrospective transition method. As a result of this election, the Company recorded a cumulative-effect adjustment of $11 million , representing an increase in accumulated deficit, with the offset to paid-in capital. During the first quarter of 2017, the Company recorded a $4 million deferred tax asset related to this adjustment, with the offset to accumulated deficit. ASU 2016-09 requires excess tax benefits and deficiencies to be recognized prospectively as part of the provision for income taxes rather than paid-in capital. The adoption did not have a material impact on the Company’s accounting of provision for income taxes. ASU 2016-09 also requires excess tax benefits to be presented as a component of operating cash flows rather than financing cash flows. The Company has adopted this requirement prospectively and accordingly, prior periods have not been adjusted. Excess tax benefits were not material for all periods presented. Additionally, ASU 2016-09 requires that employee taxes paid when an employer withholds shares for tax-withholding purposes be reported as financing activities in the consolidated statements of cash flows, which is how the Company has historically classified these amounts. Restricted Cash In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash.” ASU 2016-18 requires amounts generally described as restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the total beginning and ending amounts for the periods shown on the statement of cash flows. The guidance is effective for annual and interim periods beginning after December 15, 2017, and is required to be adopted using a retrospective approach, with early adoption permitted. The Company adopted ASU 2016-18 in the third quarter of 2017. Other than the change in presentation within the statement of consolidated cash flows, the adoption of ASU 2016-18 did not have an impact on the Company’s consolidated financial statements. The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the consolidated balance sheet to the amounts shown in the statement of consolidated cash flows: September 30, 2017 December 31, 2016 (In millions) Cash and cash equivalents $ 1,846 $ 1,377 Restricted cash 96 — Total cash, cash equivalents, and restricted cash shown in the statement of consolidated cash flows $ 1,942 $ 1,377 For information regarding the restricted cash balance, please refer to Note 2—Acquisitions and Divestitures. New Pronouncements Issued But Not Yet Adopted In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, and the Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. Early adoption is permitted; however, the Company does not intend to early adopt. As part of the assessment to date, the Company has formed an implementation work team and is continuing to evaluate contracts to determine the impact this ASU will have on its consolidated financial statements. At this time, the Company cannot reasonably estimate the financial impact this will have on its consolidated financial statements; however, the Company believes adoption and implementation of this ASU will significantly impact its balance sheet, resulting in an increase in both assets and liabilities relating to its leasing activities. In May 2014, the FASB and the International Accounting Standards Board (IASB) issued a joint revenue recognition standard, ASU 2014-09, “Revenue from Contracts with Customers (Topic 606).” The new standard removes inconsistencies in existing standards, changes the way companies recognize revenue from contracts with customers, and increases disclosure requirements. The codification was amended through additional ASUs and, as amended, 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. The guidance is 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 continues to make progress on evaluating the accounting implications of this ASU and its assessment of contracts with customers is largely complete. Based on the Company’s evaluation to date, it does not expect the adoption of this ASU to have a material impact on net earnings, however, the Company is analyzing whether the classification of certain items in revenue and expense will be impacted. The Company continues to evaluate the disclosure requirements, develop accounting policies, and assess changes to the relevant business processes and the control activities within them as a result of the provisions of this ASU. The Company will adopt the new standard on January 1, 2018, utilizing the modified retrospective approach.

SUMMARY OF SIGNIFICANT ACCOUN22

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	9 Months Ended
	Sep. 30, 2017
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 the third quarters and first nine months of 2017 and 2016 : Quarter Ended September 30, Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Oil and Gas Property: Proved $ — $ 355 $ — $ 423 Unproved 160 114 214 222
Schedule of cash, cash equivalents, and restricted cash	The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the consolidated balance sheet to the amounts shown in the statement of consolidated cash flows: September 30, 2017 December 31, 2016 (In millions) Cash and cash equivalents $ 1,846 $ 1,377 Restricted cash 96 — Total cash, cash equivalents, and restricted cash shown in the statement of consolidated cash flows $ 1,942 $ 1,377

ACQUISITIONS AND DIVESTITURES A

ACQUISITIONS AND DIVESTITURES ACQUISITIONS AND DIVESTITURES (Tables)	9 Months Ended
	Sep. 30, 2017
Business Combinations [Abstract]
Summary of assets and liabilities at closing	The components of the Company’s loss from discontinued operations were as follows: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Loss from Australia divestiture $ — $ (23 ) $ — $ (23 ) Loss from Argentina divestiture — (10 ) — (10 ) Loss from discontinued operations, net of tax $ — $ (33 ) $ — $ (33 ) A summary of the assets and liabilities at closing of the August transactions is detailed below: (In millions) ASSETS Current assets $ 110 Property, plant & equipment 1,132 Total Assets $ 1,242 LIABILITIES Current liabilities, excluding asset retirement obligation $ 120 Asset retirement obligation 780 Other long-term liabilities 46 Total Liabilities $ 946

DERIVATIVE INSTRUMENTS AND HE24

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of commodity derivative positions	As of September 30, 2017 , Apache had the following open crude oil derivative positions: Put Options (1)(2) Production Period Settlement Index Mbbls Weighted Average Strike Price October—December 2017 NYMEX WTI 8,464 $50.00 October—December 2017 Dated Brent 7,636 $51.00 (1) The remaining unamortized premium paid as of September 30, 2017 , was $50 million . (2) Subsequent to September 30, 2017 , Apache entered into put option contracts settling against Dated Brent totaling 3,650 Mbbls with a strike price of $50 for the calendar year 2018. Fixed-Price Swaps Collars (3) Call Options (4) Production Period Settlement Index Mbbls Weighted Average Fixed Price Mbbls Weighted Average Floor Price Weighted Average Ceiling Price Mbbls Strike Price January—June 2018 NYMEX WTI 2,715 $51.23 2,715 $45.00 $56.45 — — January—June 2018 Dated Brent 2,172 $54.57 2,172 $50.00 $58.77 — — January—December 2018 NYMEX WTI — — 6,023 $45.00 $57.02 6,023 $60.00 (3) Subsequent to September 30, 2017 , Apache entered into crude oil contracts settling against NYMEX WTI totaling 730 Mbbls with a floor and ceiling of $45.00 and $56.90 , respectively, for the calendar year 2018. (4) The remaining unamortized premium paid as of September 30, 2017 , was $9 million . As of September 30, 2017 , Apache had the following open natural gas derivative positions: Fixed-Price Swaps (1) Production Period Settlement Index MMBtu (in 000’s) Weighted Average Fixed Price October—December 2017 NYMEX Henry Hub 4,370 $3.32 January—March 2018 NYMEX Henry Hub 13,500 $3.39 January—June 2018 NYMEX Henry Hub 22,625 $3.17 April—June 2018 NYMEX Henry Hub 16,835 $2.92 July—December 2018 NYMEX Henry Hub 18,400 $2.97 (1) Subsequent to September 30, 2017 , Apache entered into fixed-price natural gas swaps settling against NYMEX Henry Hub totaling 15,180,000 MMBtu with a weighted average fixed-price of $2.95 for the second half of 2018. As of September 30, 2017 , Apache had the following open natural gas financial basis swap contracts: Production Period Settlement Index MMBtu (in 000’s) Weighted Average Price Differential January—March 2018 NYMEX Henry Hub/Waha 9,450 $(0.43) July—December 2018 NYMEX Henry Hub/Waha 33,120 $(0.53) October—December 2018 NYMEX Henry Hub/Waha 1,380 $(0.51) January—March 2019 NYMEX Henry Hub/Waha 1,350 $(0.54) January—June 2019 NYMEX Henry Hub/Waha 32,580 $(0.53) January—December 2019 NYMEX Henry Hub/Waha 14,600 $(0.45)
Schedule of derivative assets measured at fair value	The following table presents the Company’s derivative assets and liabilities measured at fair value on a recurring basis: Fair Value Measurements Using Quoted Price in Active Markets (Level 1) Significant Other Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value Netting (1) Carrying Amount (In millions) September 30, 2017 Assets: Commodity Derivative Instruments $ — $ 24 $ — $ 24 $ (7 ) $ 17 Liabilities: Commodity Derivative Instruments — 7 — 7 (7 ) — December 31, 2016 Assets: Commodity Derivative Instruments $ — $ — $ — $ — $ — $ — Liabilities: Commodity Derivative Instruments — — — — — — (1) The derivative fair values are based on analysis of each contract on a gross basis, excluding the impact of netting agreements with counterparties.
Schedule of derivative liabilities measured at fair value	The following table presents the Company’s derivative assets and liabilities measured at fair value on a recurring basis: Fair Value Measurements Using Quoted Price in Active Markets (Level 1) Significant Other Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value Netting (1) Carrying Amount (In millions) September 30, 2017 Assets: Commodity Derivative Instruments $ — $ 24 $ — $ 24 $ (7 ) $ 17 Liabilities: Commodity Derivative Instruments — 7 — 7 (7 ) — December 31, 2016 Assets: Commodity Derivative Instruments $ — $ — $ — $ — $ — $ — Liabilities: Commodity Derivative Instruments — — — — — — (1) The derivative fair values are based on analysis of each contract on a gross basis, excluding the impact of netting agreements with counterparties.
Schedule of derivative instruments on consolidated balance sheet and statement of consolidated operations	The carrying value of the Company’s derivative assets and liabilities and their locations on the consolidated balance sheet are as follows: September 30, 2017 December 31, 2016 (In millions) Current Assets: Prepaid assets and other $ 13 $ — Other Assets: Deferred charges and other 4 — Total Assets $ 17 $ — 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: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Realized gain (loss): Derivative settlements, realized gain $ 23 $ — $ 23 $ — Amortization of put premium, realized loss (50 ) — (50 ) — Unrealized loss (83 ) — (42 ) — Derivative instrument losses, net $ (110 ) $ — $ (69 ) $ —

OTHER CURRENT LIABILITIES (Tabl

OTHER CURRENT LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 2017
Payables and Accruals [Abstract]
Detail of Other Current Liabilities	The following table provides detail of the Company’s other current liabilities as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 (In millions) Accrued operating expenses $ 73 $ 110 Accrued exploration and development 691 463 Accrued compensation and benefits 99 201 Accrued interest 108 145 Accrued income taxes 68 22 Current asset retirement obligation 35 66 Refundable deposits 149 174 Other 109 77 Total other current liabilities $ 1,332 $ 1,258

ASSET RETIREMENT OBLIGATION (Ta

ASSET RETIREMENT OBLIGATION (Tables)	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the nine -month period ended September 30, 2017 : (In millions) Asset retirement obligation at December 31, 2016 $ 2,498 Liabilities incurred 39 Liabilities divested (810 ) Liabilities settled (30 ) Accretion expense 103 Revisions in estimated liabilities 66 Asset retirement obligation at September 30, 2017 1,866 Less current portion 35 Asset retirement obligation, long-term $ 1,831

DEBT AND FINANCING COSTS (Table

DEBT AND FINANCING COSTS (Tables)	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Summary of Carrying Amounts and Estimated Fair Values	The following table presents the carrying amounts and estimated fair values of the Company’s outstanding debt as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Commercial paper and committed bank facilities $ — $ — $ — $ — Notes and debentures 8,483 9,094 8,544 9,183 Total Debt $ 8,483 $ 9,094 $ 8,544 $ 9,183
Schedule of Debt	The following table presents the carrying value of the Company’s debt as of September 30, 2017 and December 31, 2016 : September 30, 2017 December 31, 2016 (In millions) Debt before unamortized discount and debt issuance costs $ 8,580 $ 8,650 Unamortized discount (48 ) (50 ) Debt issuance costs (49 ) (56 ) Total debt 8,483 8,544 Current maturities (550 ) — Long-term debt $ 7,933 $ 8,544
Components of Financing Costs, Net	The following table presents the components of Apache’s financing costs, net: For the Quarter Ended September 30, For the Nine Months Ended September 30, 2017 2016 2017 2016 (In millions) Interest expense $ 113 $ 116 $ 344 $ 348 Amortization of deferred loan costs 3 2 7 5 Capitalized interest (12 ) (13 ) (39 ) (36 ) Loss on extinguishment of debt — — 1 — Interest income (3 ) (3 ) (13 ) (6 ) Financing costs, net $ 101 $ 102 $ 300 $ 311

CAPITAL STOCK (Tables)

CAPITAL STOCK (Tables)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Reconciliation of the components of basic and diluted net loss per common share	A reconciliation of the components of basic and diluted net income (loss) per common share for the quarters and nine months ended September 30, 2017 and 2016 , is presented in the table below. For the Quarter Ended September 30, 2017 2016 Income Shares Per Share Loss Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ 63 381 $ 0.16 $ (574 ) 380 $ (1.51 ) Loss from discontinued operations — 381 — (33 ) 380 (0.09 ) Income (loss) attributable to common stock $ 63 381 $ 0.16 $ (607 ) 380 $ (1.60 ) Effect of Dilutive Securities: Stock options and other $ — 2 $ — $ — — $ — Diluted: Income (loss) from continuing operations $ 63 383 $ 0.16 $ (574 ) 380 $ (1.51 ) Loss from discontinued operations — 383 — (33 ) 380 (0.09 ) Income (loss) attributable to common stock $ 63 383 $ 0.16 $ (607 ) 380 $ (1.60 ) For the Nine Months Ended September 30, 2017 2016 Income Shares Per Share Loss Shares Per Share (In millions, except per share amounts) Basic: Income (loss) from continuing operations $ 848 381 $ 2.23 $ (1,190 ) 379 $ (3.14 ) Loss from discontinued operations — 381 — (33 ) 379 (0.08 ) Income (loss) attributable to common stock $ 848 381 $ 2.23 $ (1,223 ) 379 $ (3.22 ) Effect of Dilutive Securities: Stock options and other $ — 2 $ (0.01 ) $ — — $ — Diluted: Income (loss) from continuing operations $ 848 383 $ 2.22 $ (1,190 ) 379 $ (3.14 ) Loss from discontinued operations — 383 — (33 ) 379 (0.08 ) Income (loss) attributable to common stock $ 848 383 $ 2.22 $ (1,223 ) 379 $ (3.22 )

ACCUMULATED OTHER COMPREHENSI29

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table describes changes to the Company’s accumulated other comprehensive loss by component for the nine -month period ended September 30, 2017 : Currency Translation Adjustment Pension and Postretirement Benefit Plan Total (In millions) Accumulated other comprehensive loss at December 31, 2016 $ (109 ) $ (3 ) $ (112 ) Currency translation adjustment divested (1) 109 — 109 Accumulated other comprehensive loss at September 30, 2017 $ — $ (3 ) $ (3 ) (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 loss. This currency translation loss was recognized as a reduction of the net gain on divestiture during the third quarter of 2017 in connection with the Canada divestitures. For more information regarding these divestitures, please refer to Note 2—Acquisitions and Divestitures.

BUSINESS SEGMENT INFORMATION (T

BUSINESS SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2017
Segment Reporting [Abstract]
Financial Segment Information	Financial information for each area is presented below: United States Canada (1) Egypt (2) North Sea Other International Total (In millions) For the Quarter Ended September 30, 2017 Oil and Gas Production Revenues $ 550 $ 36 $ 543 $ 260 $ — $ 1,389 Operating Income (Loss) (3) $ (114 ) $ (1 ) $ 226 $ 16 $ (1 ) $ 126 Other Income (Expense): Gain on divestitures, net 296 Derivative instrument losses, net (110 ) General and administrative (98 ) Transaction, reorganization, and separation (20 ) Financing costs, net (101 ) Income Before Income Taxes $ 93 For the Nine Months Ended September 30, 2017 Oil and Gas Production Revenues $ 1,593 $ 231 $ 1,655 $ 768 $ — $ 4,247 Operating Income (Loss) (3) $ (71 ) $ (33 ) $ 740 $ 59 $ (24 ) $ 671 Other Income (Expense): Gain on divestitures, net 616 Derivative instrument losses, net (69 ) Other 43 General and administrative (307 ) Transaction, reorganization, and separation (14 ) Financing costs, net (300 ) Income Before Income Taxes $ 640 Total Assets $ 13,105 $ — $ 4,906 $ 3,770 $ 54 $ 21,835 United States Canada (1) Egypt (2) North Sea Other International Total (In millions) For the Quarter Ended September 30, 2016 Oil and Gas Production Revenues $ 524 $ 87 $ 581 $ 247 $ — $ 1,439 Operating Income (Loss) (4) $ (17 ) $ (466 ) $ 263 $ (455 ) $ (13 ) $ (688 ) Other Income (Expense): Gain on divestitures, net 5 Other (6 ) General and administrative (102 ) Transaction, reorganization, and separation (12 ) Financing costs, net (102 ) Loss From Continuing Operations Before Income Taxes $ (905 ) For the Nine Months Ended September 30, 2016 Oil and Gas Production Revenues $ 1,453 $ 243 $ 1,515 $ 701 $ — $ 3,912 Operating Income (Loss) (4) $ (283 ) $ (586 ) $ 525 $ (557 ) $ (13 ) $ (914 ) Other Income (Expense): Gain on divestitures, net 21 Other (30 ) General and administrative (298 ) Transaction, reorganization, and separation (36 ) Financing costs, net (311 ) Loss From Continuing Operations Before Income Taxes $ (1,568 ) Total Assets $ 12,299 $ 1,630 $ 5,320 $ 3,851 $ 49 $ 23,149 (1) During the third quarter of 2017, Apache completed the sale of its Canadian operations. For more information regarding this divestiture, please refer to Note 2—Acquisitions and Divestitures. (2) Includes a noncontrolling interest in Egypt. (3) Operating income (loss) consists of oil and gas production revenues less lease operating expenses, gathering and transportation costs, taxes other than income, exploration costs, depreciation, depletion, and amortization, asset retirement obligation accretion, and impairments. The operating income (loss) of U.S. includes leasehold impairments totaling $160 million for the third quarter of 2017 . The operating income (loss) of U.S., Canada, and North Sea includes leasehold and other asset impairments totaling $212 million , $2 million , and $8 million , respectively, for the first nine months of 2017 . (4) The operating income (loss) of U.S., Canada, and North Sea includes leasehold, property, and other asset impairments totaling $46 million , $423 million , and $481 million , respectively, for the third quarter of 2016 . The operating income (loss) of U.S., Canada, and North Sea includes leasehold, property, and other asset impairments totaling $212 million , $433 million , and $586 million , respectively, for the first nine months of 2016 .

SUMMARY OF SIGNIFICANT ACCOUN31

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Detail) - USD ($)	Jan. 01, 2016	Dec. 31, 2015	Sep. 30, 2017	Mar. 31, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016	Jun. 30, 2016
Schedule Of Significant Accounting Policies [Line Items]
Asset impairment charges			$ 0		$ 836,000,000	$ 8,000,000	$ 1,009,000,000
U.K. Petroleum Revenue Tax rate	0.00%	35.00%
Impairment of certain GTP assets							105,000,000
Oil and gas property, fair value					163,000,000		163,000,000		$ 143,000,000
Cash and cash equivalents			1,846,000,000			1,846,000,000		$ 1,377,000,000
Restricted cash			96,000,000			96,000,000		0
Total cash, cash equivalents, and restricted cash shown in the statement of consolidated cash flows		$ 1,467,000,000	1,942,000,000		1,230,000,000	1,942,000,000	1,230,000,000	1,377,000,000
Accounting Standards Update 2016-09, Excess Tax Benefit Component
Schedule Of Significant Accounting Policies [Line Items]
Deferred tax assets								4,000,000
Paid-In Capital | Accounting Standards Update 2016-09
Schedule Of Significant Accounting Policies [Line Items]
Cumulative effect of new accounting principle								11,000,000
Accumulated Deficit | Accounting Standards Update 2016-09
Schedule Of Significant Accounting Policies [Line Items]
Cumulative effect of new accounting principle								(11,000,000)
Accumulated Deficit | Accounting Standards Update 2016-09, Excess Tax Benefit Component
Schedule Of Significant Accounting Policies [Line Items]
Cumulative effect of new accounting principle								$ 4,000,000
Gas Gathering, Transmission, and Processing (GTP) Assets
Schedule Of Significant Accounting Policies [Line Items]
Oil and gas property, fair value					175,000,000		175,000,000
Oil and Gas Properties, Proved
Schedule Of Significant Accounting Policies [Line Items]
Impairments for oil and gas properties			0		355,000,000	0	423,000,000
Oil and Gas Properties, Unproved
Schedule Of Significant Accounting Policies [Line Items]
Impairments for oil and gas properties			$ 160,000,000		114,000,000	$ 214,000,000	222,000,000
Recoverable PRT Decommissioning Asset
Schedule Of Significant Accounting Policies [Line Items]
Asset impairment charges				$ 8,000,000
Impairments for oil and gas properties					481,000,000		481,000,000
Canada | Oil and Gas Properties, Proved
Schedule Of Significant Accounting Policies [Line Items]
Impairments for oil and gas properties					$ 355,000,000
US and Canada | Oil and Gas Properties, Proved
Schedule Of Significant Accounting Policies [Line Items]
Impairments for oil and gas properties							$ 423,000,000

ACQUISITIONS AND DIVESTITURES -

ACQUISITIONS AND DIVESTITURES - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2017	Aug. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Business Acquisition [Line Items]
Refundable deposits for sale of non-core assets								$ 40
Gain on sale of non-core assets			$ 296		$ 5	$ 616	$ 21
Refundable deposits			149			149		$ 174
Leasehold and property acquisitions			75		51	142	169
Transaction, reorganization, and separation			20		12	14	36
Scottish Area Gas Evacuation System
Business Acquisition [Line Items]
Equity ownership percentage								30.28%
Beryl Pipeline
Business Acquisition [Line Items]
Equity ownership percentage								60.56%
Permian Region
Business Acquisition [Line Items]
Proceeds from sale of non-core assets						783
Gain on sale of non-core assets						594
Disposed of by sale | Midale and House Mountain
Business Acquisition [Line Items]
Gain (loss) recognized on sale				$ (52)
Disposed of by sale | Apache Canada Ltd. (ACL)
Business Acquisition [Line Items]
Proceeds from divestiture	$ 228	$ 478
Gain (loss) recognized on sale			74
Currency translation losses recorded in Accumulated Other Comprehensive Loss			109			109
Pretax losses from operations			$ 12		$ 483	$ 141	$ 644
Restricted Cash | Disposed of by sale | Apache Canada Ltd. (ACL)
Business Acquisition [Line Items]
Proceeds from divestiture		$ 96

ACQUISITIONS AND DIVESTITURES33

ACQUISITIONS AND DIVESTITURES - Summary of Assets and Liabilities of August Canada Divestitures (Details) - Disposed of by sale - Apache Canada Ltd. (ACL) $ in Millions	Aug. 31, 2017USD ($)
ASSETS
Current assets	$ 110
Property, plant & equipment	1,132
Total Assets	1,242
LIABILITIES
Current liabilities, excluding asset retirement obligation	120
Asset retirement obligation	780
Other long-term liabilities	46
Total Liabilities	$ 946

ACQUISITIONS AND DIVESTITURES34

ACQUISITIONS AND DIVESTITURES - Components of Loss from Discontinued Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net loss from discontinued operations	$ 0	$ (33)	$ 0	$ (33)
Discontinued operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net loss from discontinued operations	0	(33)	0	(33)
Apache Australia Operation | Discontinued operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net loss from discontinued operations	0	(23)	0	(23)
Apache Argentina Operation | Discontinued operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net loss from discontinued operations	$ 0	$ (10)	$ 0	$ (10)

DERIVATIVE INSTRUMENTS AND HE35

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Instruments (Detail) bbl in Thousands, $ in Millions	1 Months Ended	9 Months Ended
	Nov. 02, 2017MMBTU$ / MMBTU$ / bblbbl	Sep. 30, 2017USD ($)MMBTUCounterparty$ / MMBTU$ / bblbbl
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of derivative counterparties | Counterparty		14
Put Options | Crude Oil
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative remaining unamortized premium paid | $		$ 50
Put Options | October—December 2017 | Crude Oil | NYMEX WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		8,464
Derivative, weighted average strike price (USD per bbl) | $ / bbl		50
Put Options | October—December 2017 | Crude Oil | Dated Brent
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		7,636
Derivative, weighted average strike price (USD per bbl) | $ / bbl		51
Put Options | January—December 2018 | Crude Oil | Dated Brent | Subsequent Event
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl	3,650
Derivative, weighted average strike price (USD per bbl) | $ / bbl	50
Fixed-Price Swaps | October—December 2017 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		4,370,000
Derivative, weighted average fixed price (USD per MMBtu)		3.32
Fixed-Price Swaps | January—June 2018 | Crude Oil | NYMEX WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		2,715
Derivative, weighted average fixed price (USD per MMBtu)		51.23
Fixed-Price Swaps | January—June 2018 | Crude Oil | Dated Brent
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		2,172
Derivative, weighted average fixed price (USD per MMBtu)		54.57
Fixed-Price Swaps | January—June 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		22,625,000
Derivative, weighted average fixed price (USD per MMBtu)		3.17
Fixed-Price Swaps | January - March 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		13,500,000
Derivative, weighted average fixed price (USD per MMBtu)		3.39
Fixed-Price Swaps | April—June 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		16,835,000
Derivative, weighted average fixed price (USD per MMBtu)		2.92
Fixed-Price Swaps | July - December 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		18,400,000
Derivative, weighted average fixed price (USD per MMBtu)		2.97
Fixed-Price Swaps | July - December 2018 | Natural Gas | NYMEX Henry Hub | Subsequent Event
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, weighted average fixed price (USD per MMBtu)	2.95
Fixed-Price Swaps | January—December 2018 | Natural Gas | NYMEX Henry Hub | Subsequent Event
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	15,180,000
Collars | January—June 2018 | Crude Oil | NYMEX WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		2,715
Derivative, weighted average floor price (USD per bbl)		45
Derivative, weighted average ceiling price (USD per bbl)		56.45
Collars | January—June 2018 | Crude Oil | Dated Brent
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		2,172
Derivative, weighted average floor price (USD per bbl)		50
Derivative, weighted average ceiling price (USD per bbl)		58.77
Collars | January—December 2018 | Crude Oil | NYMEX WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		6,023
Derivative, weighted average floor price (USD per bbl)		45
Derivative, weighted average ceiling price (USD per bbl)		57.02
Collars | January—December 2018 | Crude Oil | NYMEX WTI | Subsequent Event
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl	730
Derivative, weighted average floor price (USD per bbl)	45
Derivative, weighted average ceiling price (USD per bbl)	56.90
Call Options | Crude Oil
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative remaining unamortized premium paid | $		$ 9
Call Options | January—December 2018 | Crude Oil | NYMEX WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl		6,023
Derivative, weighted average strike price (USD per bbl) | $ / bbl		60
Finanical Basis Swaps | January - March 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		9,450,000
Weighted Average Price Differential		(0.43)
Finanical Basis Swaps | October - December 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		1,380,000
Weighted Average Price Differential		(0.51)
Finanical Basis Swaps | July - December 2018 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		33,120,000
Weighted Average Price Differential		(0.53)
Finanical Basis Swaps | January—March 2019 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		1,350,000
Weighted Average Price Differential		(0.54)
Finanical Basis Swaps | January—June 2019 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		32,580,000
Weighted Average Price Differential		(0.53)
Finanical Basis Swaps | January - December 2019 | Natural Gas | NYMEX Henry Hub
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU		14,600,000
Weighted Average Price Differential		(0.45)

DERIVATIVE INSTRUMENTS AND HE36

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Assets and Liabilities Measured at Fair Value (Details) - Commodity Derivative Instruments - Recurring - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Derivative [Line Items]
Derivative asset, fair value	$ 24	$ 0
Derivative asset, netting	(7)	0
Derivative asset	17	0
Derivative liability, fair value	7	0
Derivative liability, netting	(7)	0
Derivative liability	0	0
Quoted Price in Active Markets (Level 1)
Derivative [Line Items]
Derivative asset, fair value	0	0
Derivative liability, fair value	0	0
Significant Other Inputs (Level 2)
Derivative [Line Items]
Derivative asset, fair value	24	0
Derivative liability, fair value	7	0
Significant Unobservable Inputs (Level 3)
Derivative [Line Items]
Derivative asset, fair value	0	0
Derivative liability, fair value	$ 0	$ 0

DERIVATIVE INSTRUMENTS AND HE37

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Assets and Liabilities and Locations on Consolidated Balance Sheet (Details) - Recurring - Commodity Derivative Instruments - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative asset	$ 17	$ 0
Current Assets: Prepaid assets and other
Derivatives, Fair Value [Line Items]
Derivative asset	13	0
Other Assets: Deferred charges and other
Derivatives, Fair Value [Line Items]
Derivative asset	$ 4	$ 0

DERIVATIVE INSTRUMENTS AND HE38

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Activities Recorded in the Statement of Consolidated Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Realized gain (loss):
Unrealized loss			$ (42)	$ 0
Not Designated as Hedging Instrument
Realized gain (loss):
Derivative settlements, realized gain	$ 23	$ 0	23	0
Amortization of put premium, realized loss	(50)	0	(50)	0
Unrealized loss	(83)	0	(42)	0
Derivative instrument losses, net	$ (110)	$ 0	$ (69)	$ 0

CAPITALIZED EXPLORATORY WELL 39

CAPITALIZED EXPLORATORY WELL COSTS (Detail) - USD ($)	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Extractive Industries [Abstract]
Capitalized exploratory well costs	$ 369,000,000	$ 264,000,000
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 0

OTHER CURRENT LIABILITIES (Deta

OTHER CURRENT LIABILITIES (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Payables and Accruals [Abstract]
Accrued operating expenses	$ 73	$ 110
Accrued exploration and development	691	463
Accrued compensation and benefits	99	201
Accrued interest	108	145
Accrued income taxes	68	22
Current asset retirement obligation	35	66
Refundable deposits	149	174
Other	109	77
Total other current liabilities	$ 1,332	$ 1,258

ASSET RETIREMENT OBLIGATION (De

ASSET RETIREMENT OBLIGATION (Detail) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation at the beginning of period	$ 2,498
Liabilities incurred	39
Liabilities divested	(810)
Liabilities settled	(30)
Accretion expense	103
Revisions in estimated liabilities	66
Asset retirement obligation at the end of period	1,866
Less current portion	35	$ 66
Asset retirement obligation, long-term	$ 1,831	$ 2,432

INCOME TAXES (Detail)

INCOME TAXES (Detail) - USD ($) $ in Millions	Jan. 01, 2016	Sep. 30, 2017	Jun. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2015
Income Tax Contingency [Line Items]
Deferred income tax expense (benefit)		$ (111)		$ (529)	$ (758)	$ (755)
Current tax benefit		30
North Sea
Income Tax Contingency [Line Items]
Deferred income tax expense (benefit)				$ (235)
Effective income tax rate	40.00%						50.00%
Apache Canada Ltd. (ACL) | Disposed of by sale
Income Tax Contingency [Line Items]
Deferred income tax expense (benefit)		$ 2	$ (674)

DEBT AND FINANCING COSTS - Summ

DEBT AND FINANCING COSTS - Summary of Carrying Amounts and Estimated Fair Values (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	$ 8,483	$ 8,544
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	9,094	9,183
Notes and debentures | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	8,483	8,544
Notes and debentures | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	9,094	9,183
Commercial Paper | Commercial paper and committed bank facilities | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	0	0
Commercial Paper | Commercial paper and committed bank facilities | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument	$ 0	$ 0

DEBT AND FINANCING COSTS - Sche

DEBT AND FINANCING COSTS - Schedule of Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Long-term debt	$ 7,933	$ 8,544
Unsecured Debt
Debt Instrument [Line Items]
Debt before unamortized discount and debt issuance costs	8,580	8,650
Unamortized discount	(48)	(50)
Debt issuance costs	(49)	(56)
Total debt	8,483	8,544
Current maturities	(550)	0
Long-term debt	$ 7,933	$ 8,544

DEBT AND FINANCING COSTS - Addi

DEBT AND FINANCING COSTS - Additional Information (Detail)	1 Months Ended	3 Months Ended			9 Months Ended
	Jan. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)Contract	Sep. 30, 2016USD ($)	Sep. 30, 2017GBP (£)	Aug. 31, 2017USD ($)	Nov. 30, 2016USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding, amount | £							£ 147,500,000
Loss on extinguishment of debt	$ 1,000,000	$ 0		$ 0	$ 1,000,000	$ 0
Commercial Paper
Debt Instrument [Line Items]
Debt instrument, face amount		3,500,000,000			$ 3,500,000,000
Debt instrument term					270 days
Letter of Credit
Debt Instrument [Line Items]
Number of debt instruments (in contracts) | Contract					3
Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity		3,500,000,000			$ 3,500,000,000
Credit Facility Matures in June 2020 | Letter of Credit
Debt Instrument [Line Items]
Line of credit amount		750,000,000			$ 750,000,000
Credit Facility Matures in June 2020 | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, number of extension options | Contract					2
Extended financing agreement term					1 year
Credit Facility Matures in February 2020 | Letter of Credit
Debt Instrument [Line Items]
Debt instrument, face amount | £							900,000,000
Credit facility maximum borrowing capacity | £							£ 1,075,000,000
Line of credit amount		0			$ 0
Unsecured Debt
Debt Instrument [Line Items]
Debt instrument, face amount		8,580,000,000	$ 8,650,000,000		8,580,000,000
Unsecured Debt | 7% senior notes due February 1, 2018
Debt Instrument [Line Items]
Debt instrument, face amount		$ 150,000,000			$ 150,000,000
Debt instrument, stated interest rate		7.00%			7.00%		7.00%
Unsecured Debt | 6.9% senior notes due September 15, 2018
Debt Instrument [Line Items]
Debt instrument, face amount		$ 400,000,000			$ 400,000,000
Debt instrument, stated interest rate		6.90%			6.90%		6.90%
Senior Notes
Debt Instrument [Line Items]
Repurchased face amount of debt	69,000,000		181,000,000
Senior notes purchased and canceled	71,000,000		182,000,000
Debt instrument, premium amount	$ 1,000,000		$ 500,000
Senior Notes | 7.75% Senior Notes Due In 2029
Debt Instrument [Line Items]
Debt instrument, face amount								$ 300,000,000
Debt instrument, stated interest rate								7.75%
Maximum | Credit Facility Matures in June 2020 | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility aggregate commitment amount					$ 4,500,000,000
Maximum | Senior Notes
Debt Instrument [Line Items]
Repurchased face amount of debt									$ 250,000,000

DEBT AND FINANCING COSTS - Comp

DEBT AND FINANCING COSTS - Components of Financing Costs, Net (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Jan. 31, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Debt Disclosure [Abstract]
Interest expense		$ 113	$ 116	$ 344	$ 348
Amortization of deferred loan costs		3	2	7	5
Capitalized interest		(12)	(13)	(39)	(36)
Loss on extinguishment of debt	$ 1	0	0	1	0
Interest income		(3)	(3)	(13)	(6)
Financing costs, net		$ 101	$ 102	$ 300	$ 311

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Detail) AUD in Millions	Jul. 17, 2017ActionCompany	Mar. 21, 2016USD ($)	Mar. 20, 2016USD ($)	Sep. 30, 2017USD ($)	Sep. 22, 2017AUD	Jun. 06, 2016USD ($)
Commitment And Contingencies [Line Items]
Accrued liability for legal contingencies				$ 37,000,000
Undiscounted reserve for environmental remediation				$ 4,000,000
Apollo Exploration Lawsuit
Commitment And Contingencies [Line Items]
Plaintiffs alleged damages		$ 500,000,000
Apollo Exploration Lawsuit | Minimum
Commitment And Contingencies [Line Items]
Plaintiffs alleged damages			$ 1,100,000,000
Damages as a result of global warning
Commitment And Contingencies [Line Items]
Number of separate litigation actions | Action	3
Number of defendants | Company	30
Australian Operations Divestiture Dispute | Australian Operations
Commitment And Contingencies [Line Items]
Divestiture of business, tax and other issues contingency amount						$ 200,000,000
Gain contingency, amount | AUD					AUD 80

CAPITAL STOCK - Net Income (los

CAPITAL STOCK - Net Income (loss) Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Basic:
Income (loss) from continuing operations	$ 63	$ (574)	$ 848	$ (1,190)
Loss from discontinued operations	0	(33)	0	(33)
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$ 63	$ (607)	$ 848	$ (1,223)
Income (loss) from continuing operations, shares	381	380	381	379
Loss from discontinued operations, shares	381	380	381	379
Income (loss) attributable to common stock, shares	381	380	381	379
Income (loss) from continuing operations (in USD per share)	$ 0.16	$ (1.51)	$ 2.23	$ (3.14)
Loss from discontinued operations (in USD per share)	0	(0.09)	0	(0.08)
Basic net income (loss) per share (in USD per share)	$ 0.16	$ (1.60)	$ 2.23	$ (3.22)
Effect of Dilutive Securities:
Stock options and other, shares	2		2
Stock options and other (in USD per share)			$ (0.01)
Diluted:
Income (loss) from continuing operations	$ 63	$ (574)	$ 848	$ (1,190)
Loss from discontinued operations	0	(33)	0	(33)
Income (loss) attributable to common stock	$ 63	$ (607)	$ 848	$ (1,223)
Income (loss) from continuing operations, shares	383	380	383	379
Loss from discontinued operations, shares	383	380	383	379
Income (loss) attributable to common stock, shares	383	380	383	379
Income (loss) from continuing operations (in USD per share)	$ 0.16	$ (1.51)	$ 2.22	$ (3.14)
Loss from discontinued operations (in USD per share)	0	(0.09)	0	(0.08)
Diluted net income (loss) per share (in USD per share)	$ 0.16	$ (1.60)	$ 2.22	$ (3.22)

CAPITAL STOCK - Additional Info

CAPITAL STOCK - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended		52 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017
Equity [Abstract]
Options and restricted stock, anti-dilutive	8,400,000	4,700,000	7,500,000	6,500,000
Dividends, common stock	$ 95	$ 95	$ 285	$ 284
Common stock, shares authorized for repurchase	40,000,000		40,000,000		40,000,000
Common stock share repurchase, shares					32,200,000
Common stock share repurchase average price (in USD per share)					$ 88.96

ACCUMULATED OTHER COMPREHENSI50

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 7,679
Currency translation adjustment divested	109
Ending Balance	8,377
Currency Translation Adjustment
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(109)
Currency translation adjustment divested	109
Ending Balance	0
Pension and Postretirement Benefit Plan
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(3)
Currency translation adjustment divested	0
Ending Balance	(3)
Accumulated Other Comprehensive Loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(112)
Ending Balance	$ (3)

BUSINESS SEGMENT INFORMATION -

BUSINESS SEGMENT INFORMATION - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2017Segment
Segment Reporting [Abstract]
Number of reporting segments	3

BUSINESS SEGMENT INFORMATION 52

BUSINESS SEGMENT INFORMATION - Financial Segment Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	$ 1,389	$ 1,439	$ 4,247	$ 3,912
Operating Income (Loss)	126	(688)	671	(914)
Other Income (Expense):
Gain on divestitures	296	5	616	21
Derivative instrument losses, net	(110)	0	(69)	0
Other		(6)	43	(30)
General and administrative	(98)	(102)	(307)	(298)
Transaction, reorganization, and separation	(20)	(12)	(14)	(36)
Financing costs, net	(101)	(102)	(300)	(311)
NET INCOME (LOSS) BEFORE INCOME TAXES	93	(905)	640	(1,568)
Total Assets	21,835	23,149	21,835	23,149	$ 22,519
Operating Segments | United States
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	550	524	1,593	1,453
Operating Income (Loss)	(114)	(17)	(71)	(283)
Other Income (Expense):
Total Assets	13,105	12,299	13,105	12,299
Asset impairments	160	46	212	212
Operating Segments | Canada
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	36	87	231	243
Operating Income (Loss)	(1)	(466)	(33)	(586)
Other Income (Expense):
Total Assets	0	1,630	0	1,630
Asset impairments		423	2	433
Operating Segments | Egypt
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	543	581	1,655	1,515
Operating Income (Loss)	226	263	740	525
Other Income (Expense):
Total Assets	4,906	5,320	4,906	5,320
Operating Segments | North Sea
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	260	247	768	701
Operating Income (Loss)	16	(455)	59	(557)
Other Income (Expense):
Total Assets	3,770	3,851	3,770	3,851
Asset impairments		481	8	586
Other International
Segment Reporting Information [Line Items]
Oil and Gas Production Revenues	0	0	0	0
Operating Income (Loss)	(1)	(13)	(24)	(13)
Other Income (Expense):
Total Assets	$ 54	$ 49	$ 54	$ 49