10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549 

FORM 10-Q 

(Mark One)  

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

OR

¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                      to                     

Commission File Number 1-4300

APACHE CORPORATION

(exact name of registrant as specified in its charter)

Delaware	41-0747868
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

One Post Oak Central, 2000 Post Oak Boulevard, Suite 100, Houston, Texas 77056-4400

(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code: (713) 296-6000

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, $0.625 par value	APA	New York Stock Exchange, Chicago Stock Exchange and NASDAQ Global Select Market
7.75% Notes Due 2029		New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  ý    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	ý	Accelerated filer	¨
Non-accelerated filer	¨	Smaller reporting company	¨
		Emerging growth company	¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes  ¨    No  ý

Number of shares of registrant’s common stock outstanding as of April 30, 2019 375,920,593

	TABLE OF CONTENTS
	DESCRIPTION
Item		Page
	PART I - FINANCIAL INFORMATION
1.	FINANCIAL STATEMENTS	1
	STATEMENT OF CONSOLIDATED OPERATIONS	1
	STATEMENT OF CONSOLIDATED CASH FLOWS	2
	CONSOLIDATED BALANCE SHEET	3
	STATEMENT OF CONSOLIDATED CHANGES IN EQUITY	4
	NOTES TO CONSOLIDATED FINANCIAL STATEMENTS	5
2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	21
3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	32
4.	CONTROLS AND PROCEDURES	33
	PART II - OTHER INFORMATION
1.	LEGAL PROCEEDINGS	34
1A.	RISK FACTORS	34
2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	34
6.	EXHIBITS	34

Forward-Looking Statements and Risk

This report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, budgets, projected revenues, projected costs, and plans and objectives of management for future operations, are forward-looking statements. Such forward-looking statements are based on our examination of historical operating trends, the information that was used to prepare our estimate of proved reserves as of December 31, 2018, and other data in our possession or available from third parties. In addition, forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “could,” “expect,” “intend,” “project,” “estimate,” “anticipate,” “plan,” “believe,” or “continue” or similar terminology. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from our expectations include, but are not limited to, our assumptions about:

• the market prices of oil, natural gas, natural gas liquids (NGLs), and other products or services;

• our commodity hedging arrangements;

• the supply and demand for oil, natural gas, NGLs, and other products or services;

• production and reserve levels;

• drilling risks;

• economic and competitive conditions;

• the availability of capital resources;

• capital expenditure and other contractual obligations;

• currency exchange rates;

• weather conditions;

• inflation rates;

• the availability of goods and services;

• legislative, regulatory, or policy changes;

• terrorism or cyber attacks;

• occurrence of property acquisitions or divestitures;

• the integration of acquisitions;

• the securities or capital markets and related risks such as general credit, liquidity, market, and interest-rate risks; and

• other factors disclosed under Items 1 and 2—Business and Properties—Estimated Proved Reserves and Future Net Cash Flows, Item 1A—Risk Factors, Item 7—Management’s Discussion and Analysis of Financial Condition and Results of Operations, Item 7A—Quantitative and Qualitative Disclosures About Market Risk and elsewhere in our most recently filed Annual Report on Form 10-K, other risks and uncertainties in our first-quarter 2019 earnings release, other factors disclosed under Part II, Item 1A—Risk Factors of this Quarterly Report on Form 10-Q, and other filings that we make with the Securities and Exchange Commission.

All subsequent written and oral forward-looking statements attributable to the Company, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements. We assume no duty to update or revise our forward-looking statements based on changes in internal estimates or expectations or otherwise.

PART I – FINANCIAL INFORMATION

ITEM 1 – FINANCIAL STATEMENTS

APACHE CORPORATION AND SUBSIDIARIES

STATEMENT OF CONSOLIDATED OPERATIONS

(Unaudited)

	For the Quarter Ended March 31,
	2019			2018
	(In millions, except per common share data)
REVENUES AND OTHER:
Oil and gas production revenues
Oil revenues	$	1,310		$	1,393
Natural gas revenues	236			222
Natural gas liquids revenues	108			118
	1,654			1,733
Derivative instrument gains (losses), net	(30		)	2
Gain on divestitures	3			7
Other	8			5
	1,635			1,747
OPERATING EXPENSES:
Lease operating expenses	365			349
Gathering, processing, and transmission	88			86
Taxes other than income	51			55
Exploration	69			76
General and administrative	123			114
Transaction, reorganization, and separation	4			—
Depreciation, depletion, and amortization	646			553
Asset retirement obligation accretion	27			27
Financing costs, net	97			99
	1,470			1,359
NET INCOME BEFORE INCOME TAXES	165			388
Current income tax provision	186			198
Deferred income tax benefit	(19		)	(16		)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(2		)	206
Net income attributable to noncontrolling interest - Egypt	44			61
Net income attributable to noncontrolling interest - Altus	1			—
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$	(47	)	$	145
NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	(0.12	)	$	0.38
Diluted	$	(0.12	)	$	0.38
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic	376			382
Diluted	376			384
DIVIDENDS DECLARED PER COMMON SHARE	$	0.25		$	0.25

The accompanying notes to consolidated financial statements

are an integral part of this statement.

1

APACHE CORPORATION AND SUBSIDIARIES

STATEMENT OF CONSOLIDATED CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
	2019			2018
	(In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) including noncontrolling interest	$	(2	)	$	206
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Unrealized derivative instrument (gains) losses, net	45			(49		)
Gain on divestitures	(3		)	(7		)
Exploratory dry hole expense and unproved leasehold impairments	33			36
Depreciation, depletion, and amortization	646			553
Asset retirement obligation accretion	27			27
Deferred income tax benefit	(19		)	(16		)
Other	9			39
Changes in operating assets and liabilities:
Receivables	8			(65		)
Inventories	(33		)	(33		)
Drilling advances	5			(41		)
Deferred charges and other	(4		)	32
Accounts payable	(50		)	66
Accrued expenses	(46		)	(139		)
Deferred credits and noncurrent liabilities	(18		)	6
NET CASH PROVIDED BY OPERATING ACTIVITIES	598			615
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(729		)	(737		)
Leasehold and property acquisitions	(15		)	(12		)
Additions to Altus gathering, processing, and transmission facilities	(119		)	(128		)
Altus equity method interests	(118		)	—
Proceeds from sale of oil and gas properties	9			9
Other, net	34			(22		)
NET CASH USED IN INVESTING ACTIVITIES	(938		)	(890		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper	159			—
Payments on fixed-rate debt	—			(150		)
Distributions to noncontrolling interest - Egypt	(107		)	(69		)
Dividends paid	(94		)	(95		)
Other	(5		)	(2		)
NET CASH USED IN FINANCING ACTIVITIES	(47		)	(316		)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(387		)	(591		)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	714			1,668
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	327		$	1,077
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest	$	115		$	140
Income taxes paid, net of refunds	165			191

The accompanying notes to consolidated financial statements

are an integral part of this statement.

2

APACHE CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)

In millions except share and per-share amounts	March 31, 2019			December 31, 2018
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ($177 and $450, respectively, related to Altus VIE)	$	327		$	714
Receivables, net of allowance	1,185			1,194
Inventories ($6 and $6, respectively, related to Altus VIE)	438			401
Drilling advances	213			218
Assets held for sale	217			—
Prepaid assets and other	124			160
	2,504			2,687
PROPERTY AND EQUIPMENT:
Oil and gas, on the basis of successful efforts accounting:
Proved properties	42,462			42,345
Unproved properties and properties under development	1,371			1,435
Gathering, processing, and transmission facilities ($1,353 and $1,251, respectively, related to Altus VIE)	1,958			1,856
Other ($38 and nil, respectively, related to Altus VIE)	1,154			1,120
	46,945			46,756
Less: Accumulated depreciation, depletion, and amortization ($32 and $24, respectively, related to Altus VIE)	(28,654		)	(28,335		)
	18,291			18,421
OTHER ASSETS:
Equity method interests ($209 and $91, respectively, related to Altus VIE)	209			121
Deferred charges and other	747			353
	$	21,751		$	21,582
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	679		$	709
Current debt ($29 and nil, respectively, related to Altus VIE)	339			151
Other current liabilities (Note 6) ($72 and $85, respectively, related to Altus VIE)	1,356			1,341
	2,374			2,201
LONG-TERM DEBT	8,094			8,093
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	370			391
Asset retirement obligation ($30 and $29, respectively, related to Altus VIE)	1,879			1,866
Other	425			219
	2,674			2,476
COMMITMENTS AND CONTINGENCIES (Note 10)
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 416,874,466 and 415,692,116 shares issued, respectively	261			260
Paid-in capital	12,009			12,106
Accumulated deficit	(2,095		)	(2,048		)
Treasury stock, at cost, 40,964,193 and 40,995,894 shares, respectively	(3,190		)	(3,192		)
Accumulated other comprehensive income	4			4
APACHE SHAREHOLDERS’ EQUITY	6,989			7,130
Noncontrolling interest - Egypt	1,212			1,275
Noncontrolling interest - Altus	408			407
TOTAL EQUITY	8,609			8,812
	$	21,751		$	21,582

The accompanying notes to consolidated financial statements are an integral part of this statement.

3

APACHE CORPORATION AND SUBSIDIARIES

STATEMENT OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)

	Common Stock		Paid-In Capital			Accumulated Deficit			Treasury Stock			Accumulated Other Comprehensive Income		APACHE SHAREHOLDERS’ EQUITY			Noncontrolling Interest			TOTAL EQUITY
	(In millions)
BALANCE AT DECEMBER 31, 2017	$	259	$	12,128		$	(2,088	)	$	(2,887	)	$	4	$	7,416		$	1,375		$	8,791
Net income attributable to common stock	—		—			145			—			—		145			61			206
Distributions to noncontrolling interest	—		—			—			—			—		—			(69		)	(69		)
Common dividends ($0.25 per share)	—		(96		)	—			—			—		(96		)	—			(96		)
Other	—		37			—			—			—		37			—			37
BALANCE AT MARCH 31, 2018	$	259	$	12,069		$	(1,943	)	$	(2,887	)	$	4	$	7,502		$	1,367		$	8,869
BALANCE AT DECEMBER 31, 2018	$	260	$	12,106		$	(2,048	)	$	(3,192	)	$	4	$	7,130		$	1,682		$	8,812
Net loss attributable to common stock	—		—			(47		)	—			—		(47		)	—			(47		)
Net income attributable to noncontrolling interest - Egypt	—		—			—			—			—		—			44			44
Net income attributable to noncontrolling interest - Altus	—		—			—			—			—		—			1			1
Distributions to noncontrolling interest - Egypt	—		—			—			—			—		—			(107		)	(107		)
Common dividends ($0.25 per share)	—		(94		)	—			—			—		(94		)	—			(94		)
Other	1		(3		)	—			2			—		—			—			—
BALANCE AT MARCH 31, 2019	$	261	$	12,009		$	(2,095	)	$	(3,190	)	$	4	$	6,989		$	1,620		$	8,609

The accompanying notes to consolidated financial statements

are an integral part of this statement.

4

APACHE CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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, with the exception of recently adopted accounting pronouncements discussed below. 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 (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, 2018, which contains a summary of the Company’s significant accounting policies and other disclosures.

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

As of March 31, 2019, 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, 2018, with the exception of Accounting Standards Update (ASU) 2016-02, “Leases (Topic 842)” (see “Leases” section in this Note 1 below).

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of Apache and its subsidiaries after elimination of intercompany balances and transactions. The Company’s undivided interests in oil and gas exploration and production ventures and partnerships are proportionately consolidated. The Company consolidates all other investments in which, either through direct or indirect ownership, Apache has more than a 50 percent voting interest or controls the financial and operating decisions. Noncontrolling interests represent third-party ownership in the net assets of a consolidated Apache subsidiary and are reflected separately in the Company’s financial statements. Sinopec International Petroleum Exploration and Production Corporation (Sinopec) owns a one-third minority participation in Apache’s Egypt oil and gas business as a noncontrolling interest, which is reflected as a separate component of equity in Apache’s consolidated balance sheet.

Additionally, third-party investors own a minority interest of approximately 21 percent of Altus Midstream Company (ALTM), which is reflected as a separate noncontrolling interest component of equity in Apache’s consolidated balance sheet. Apache consolidates the activities of ALTM, which qualifies as a variable interest entity (VIE) under GAAP. Apache has concluded that it is the primary beneficiary of the VIE, as defined in the accounting standards, since Apache has the power, through its ownership, to direct those activities that most significantly impact the economic performance of ALTM and the obligation to absorb losses or the right to receive benefits that could be potentially significant to ALTM. This conclusion was based on a qualitative analysis that considered ALTM’s governance structure, the commercial agreements between ALTM, Altus Midstream LP (collectively with ALTM, Altus), and Apache, and the voting rights established between the members, which provide Apache with the ability to control the operations of Altus.

Investments in which Apache holds less than 50 percent of the voting interest are typically accounted for under the equity method of accounting, with the balance recorded separately as “Equity method interests” in Apache’s consolidated balance sheet and results of operations recorded as a component of “Other” under “Revenues and Other” in the Company’s statement of consolidated operations.

Use of Estimates

Preparation of financial statements in conformity with GAAP 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 the estimate of income taxes. Actual results could differ from those estimates.

5

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).

Recurring fair value measurements are presented in further detail in Note 4—Derivative Instruments and Hedging Activities and Note 9—Debt and Financing Costs.

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 each of the first quarters of 2019 and 2018.

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 associated proved oil and gas properties. 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 well 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.

6

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 the carrying value of proved oil and gas properties may not be recoverable, 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 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 first quarters of 2019 and 2018:

	Quarter Ended March 31,
	2019		2018
	(In millions)
Oil and Gas Property:
Proved	$	—	$	—
Unproved	23		16

On the statement of consolidated operations, unproved leasehold impairments are recorded as a component of “Exploration” expense, and all other impairments of proved and unproved properties are recorded separately in “Impairments,” when applicable.

Gains and losses on significant divestitures of the Company’s oil and gas properties are recognized in the statement of consolidated operations. See Note 2—Acquisitions and Divestitures for more detail.

Revenue Recognition

Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, million Btu (MMBtu) of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Company considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Company’s right to payment, and transfer of legal title. In each case, the term between delivery and when payments are due is not significant.

Apache markets its own United States (U.S.) natural gas and crude oil production based on market-priced contracts. Typically, these contracts are adjusted for quality, transportation, and other market-reflective differentials. Since the Company’s production fluctuates because of operational issues, it is occasionally necessary to purchase third-party oil and gas to fulfill sales obligations and commitments. Sales proceeds related to third-party oil and gas purchases have been determined to be revenue from a customer. Proceeds for these volumes totaled $24 million and $104 million, for the periods ending March 31, 2019 and 2018, respectively. Associated purchase costs for these volumes totaled $22 million and $105 million, for the periods ending March 31, 2019 and 2018, respectively. Proceeds and costs are both recorded as “Other” under “Revenues and Other” in the statement of consolidated operations.

Internationally, Apache’s crude oil offshore the U.K. in the North Sea (North Sea) is sold under contracts with a market-based index price. Natural gas from the North Sea Beryl field is processed through the SAGE gas plant. The gas is sold to a third party at the St. Fergus entry point of the national grid on a National Balancing Point index price basis. Apache’s gas production in Egypt is sold primarily under an industry-pricing formula, a sliding scale based on Dated Brent crude oil with a minimum of

7

$1.50 per MMBtu and a maximum of $2.65 per MMBtu, plus an upward adjustment for liquids content. The Company’s Egypt oil production is sold at prices equivalent to the export market.

The Company’s Egyptian operations are conducted pursuant to production sharing contracts under which contractor partners pay all operating and capital costs for exploring and developing the concessions. A percentage of the production, generally up to 40 percent, is available to contractor partners to recover these operating and capital costs over contractually defined periods. The balance of the production is split among the contractor partners and the Egyptian General Petroleum Corporation (EGPC) on a contractually defined basis. Additionally, the contractor partner’s income taxes, which remain the liability of the contractor partners under domestic law, are paid by EGPC on behalf of the contractor partners out of EGPC’s production entitlement. Income taxes paid to the Arab Republic of Egypt on behalf of Apache as contract partner are recognized as oil and gas sales revenue and income tax expense and reflected as production and estimated reserves. Revenues related to Egypt’s tax volumes are considered revenue from a non-customer.

For the period ending March 31, 2019, revenues from customers and non-customers were $1.6 billion and $119 million, respectively. For the period ending March 31, 2018, revenues from customers and non-customers were $1.7 billion and $155 million, respectively.

Apache records trade accounts receivable for its unconditional rights to consideration arising under sales contracts with customers. The carrying value of such receivables, net of the allowance for doubtful accounts, represents estimated net realizable value. The Company routinely assesses the collectability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Receivables from contracts with customers, net of allowance for doubtful accounts, totaled $1.0 billion as of March 31, 2019 and December 31, 2018.

Apache has concluded that disaggregating revenue by geographic area and by product appropriately depicts how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. Refer to Note 12—Business Segment Information for a disaggregation of revenue by each product sold.

Leases

On January 1, 2019, Apache adopted ASU 2016-02, “Leases (Topic 842),” which requires lessees to recognize separate right-of-use (ROU) assets and lease liabilities for most leases classified as operating leases under previous GAAP. Prior to adoption, the Financial Accounting Standards Board (FASB) issued transition guidance permitting an entity the option to not evaluate under ASU 2016-02 those existing or expired land easements that were not previously accounted for as leases, as well as an option to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the financial statements. Apache elected both transitional practical expedients. Under these transition options, comparative reporting was not required, and the provisions of the standard were applied prospectively to leases in effect at the date of adoption.

As allowed under the standard, the Company also applied practical expedients to carry forward its historical assessments of whether existing agreements contain a lease, classification of existing lease agreements, and treatment of initial direct lease costs. Apache also elected to exclude short-term leases (those with terms of 12 months or less) from the balance sheet presentation and accounts for non-lease and lease components as a single lease component for all asset classes. Short-term lease expense was not material for the first quarter of 2019.

The Company determines if an arrangement is an operating or finance lease at the inception of each contract. If the contract is classified as an operating lease, Apache records an ROU asset and corresponding liability reflecting the total remaining present value of fixed lease payments over the expected term of the lease agreement. The expected term of the lease may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. If the Company’s lease does not provide an implicit rate in the contract, the Company uses its incremental borrowing rate when calculating the present value. In the normal course of business, Apache enters into various lease agreements for real estate, drilling rigs, vessels, aircraft, and equipment related to its exploration and development activities, which are typically classified as operating leases under the provisions of the standard. ROU assets are reflected within “Deferred charges and other assets” on the Company’s consolidated balance sheet, and the associated operating lease liabilities are reflected within “Other current liabilities” and “Other noncurrent liabilities,” as applicable.

Operating lease expense associated with ROU assets is recognized on a straight-line basis over the lease term. Lease expense is reflected on the statement of consolidated operations commensurate with the leased activities and nature of the services performed. Fixed operating lease expense was $55 million for the first quarter of 2019.

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In addition, the Company periodically enters into finance leases that are similar to those leases classified as capital leases under previous GAAP. Finance lease assets are included in property, plant, and equipment on the consolidated balance sheet, and the associated finance lease liabilities are reflected within “Current debt” and “Long-term debt,” as applicable. Prior periods include the reclassification of $39 million finance lease obligations from “Other noncurrent liabilities” to “Long-term debt” to conform with this presentation. There was no material impact to the Company’s statement of consolidated operations and statement of consolidated cash flows for its treatment of finance leases.

The following table represents the Company’s weighted average lease term and discount rate as of March 31, 2019:

	Operating Leases		Finance Leases
Weighted average remaining lease term	3.4 years		8.7 years
Weighted average discount rate	4.3	%	4.3	%

The undiscounted future minimum lease payments reconciled to the carrying value of the lease liabilities as of March 31, 2019 were as follows:

Net Minimum Commitments	Operating Leases(1)			Finance Leases(2)
	(In millions)
2019	$	159		$	22
2020	111			13
2021	46			3
2022	40			3
2023	24			3
Thereafter	41			39
Total future minimum lease payments	421			83
Less: imputed interest	(34		)	(15		)
Total lease liabilities	387			68
Current portion	(187		)	(30		)
Non-current portion	$	200		$	38

(1) Amounts included for drilling rig and related operational equipment obligations represent future payments associated with oil and gas operations gross of amounts billable to partners and other working interest owners. Such payments may be capitalized as a component of oil and gas properties, and either depreciated, impaired, or written off as exploration expense.

(2) Amounts represent the Company’s finance lease obligation related to physical power generators being leased on a one-year term with the right to purchase (entered into during the first quarter of 2019) and a separate lease for the Company’s Midland, Texas regional office building.

The lease liability reflected in the table above represents the Company’s fixed minimum payments that are settled in accordance with the lease terms. Actual lease payments during the period may also include variable lease components such as common area maintenance, usage-based sales taxes and rate differentials, or other similar costs that are not determinable at the inception of the lease. Variable lease payments for the period ended March 31, 2019 were $17 million.

New Pronouncements Issued But Not Yet Adopted

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments-Credit Losses.” The standard changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, held-to-maturity debt securities and loans, and requires entities to use a new forward-looking expected loss model that will result in the earlier recognition of allowance for losses. This update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Entities will apply the standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The Company is evaluating the new guidance and does not believe this standard will have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-13, “Disclosure Framework: Changes to the Disclosure Requirements for Fair Value Measurement,” which changes the disclosure requirements for fair value measurements by removing, adding, and modifying certain disclosures. ASU 2018-13 is effective for financial statements issued for annual periods beginning after December 15, 2019, and interim periods within those annual periods. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-14, “Disclosure Framework: Changes to the Disclosure Requirements for Defined Benefit Plans,” which eliminates, modifies, and adds disclosure requirements for defined benefit plans. The ASU is effective for financial statements issued for fiscal years ending after December 15, 2020. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

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In August 2018, the FASB issued ASU 2018-15, “Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract.” This pronouncement clarifies the requirements for capitalizing implementation costs in cloud computing arrangements and aligns them with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. This pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted, including adoption in any interim period for which financial statements have not been issued. The Company is currently evaluating the impact of adoption of this ASU on its consolidated financial statements and does not expect it to have a material impact.

2. ACQUISITIONS AND DIVESTITURES

2019 Activity

During the first quarter of 2019, Apache completed leasehold and property acquisitions for total cash consideration of $15 million primarily in its U.S. onshore regions. During the first quarter, the Company also completed the sale of certain non-core assets, primarily in the Permian region, in multiple transactions for total cash proceeds of $9 million. The Company recognized a total gain of approximately $3 million upon closing of these transactions.

In March 2019, Apache entered into an agreement to sell certain non-core assets in Oklahoma for $245 million, subject to normal and customary closing adjustments. As a result of the agreement, the associated assets and liabilities qualified as held for sale as of March 31, 2019. Property, plant, and equipment totaling $217 million were classified as current assets held for sale, and an asset retirement obligation of $6 million was classified as a current liability held for sale. The transaction is expected to close in the second quarter of 2019.

Subsequent to March 31, 2019, Apache entered into an agreement to sell certain non-core assets in south Texas for $43 million, subject to normal and customary closing adjustments. The transaction is expected to close in the second quarter of 2019. No material gain or loss is expected on the sale.

2018 Activity

During the first quarter of 2018, Apache completed $12 million of leasehold and property acquisitions primarily in its U.S. onshore regions. During the first quarter, the Company also completed the sale of certain non-core assets, primarily in the Permian region, in multiple transactions for total cash proceeds of $9 million. The Company recognized a total gain of approximately $7 million during the first quarter upon closing of these transactions.

3.   CAPITALIZED EXPLORATORY WELL COSTS

The Company’s capitalized exploratory well costs were $123 million and $159 million at March 31, 2019 and December 31, 2018, respectively. The decrease is primarily attributable to successful transfers of well costs, partially offset by additional drilling activities during the period. No suspended exploratory well costs previously capitalized for greater than one year at December 31, 2018 were charged to dry hole expense during the three months ended March 31, 2019. 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 proved reserves can be attributed to these projects.

4.   DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

Objectives and Strategies

The Company is exposed to fluctuations in crude oil and natural gas prices, currency exchange rates, and interest rates. The Company utilizes various types of derivative financial instruments to manage fluctuations in cash flows resulting from these fluctuations. Apache has elected not to designate any of its derivative contracts as cash flow hedges.

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 March 31, 2019, 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.

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Derivative Instruments

Commodity Derivative Instruments

As of March 31, 2019, Apache had the following open crude oil financial basis swap contracts:

Production Period	Settlement Index	Mbbls	Weighted Average Price Differential
April—September 2019	Midland-WTI/Cushing-WTI	4,941	$(8.60)
October—December 2019	Midland-WTI/Cushing-WTI	1,380	$(3.72)

As of March 31, 2019, Apache had the following open natural gas costless collar contracts:

Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Floor Price	Weighted Average Ceiling Price
April—June 2019	NYMEX Henry Hub	9,100	$3.00	$3.92

As of March 31, 2019, Apache had the following open natural gas financial basis swap contracts:

		Basis Swap Purchased		Basis Swap Sold
Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Price Differential	MMBtu (in 000’s)	Weighted Average Price Differential
April—June 2019	NYMEX Henry Hub/Waha	10,920	$(1.74)	16,380	$(0.53)
April—June 2019	NYMEX Henry Hub/EP Permian	—	—	10,920	$(1.58)
April—December 2019	NYMEX Henry Hub/Waha	—	—	11,000	$(0.45)

Foreign Currency Derivative Instruments

Apache has open foreign currency costless collar contracts in GBP/USD for £12.5 million per each calendar month for 2019 with a weighted average floor and ceiling price of $1.20 and $1.35, respectively.

Interest Rate Derivative Instruments

Apache has open U.S. treasury lock contracts with an aggregate notional amount of $400 million.

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Fair Value Measurements

The fair values of the Company’s derivative contracts 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 futures pricing for the underlying positions 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)
March 31, 2019
Assets:
Commodity Derivative Instruments	$	—	$	50	$	—	$	50	$	(14	)	$	36
Foreign Currency Derivative Instruments	—		1		—		1		—			1
Liabilities:
Commodity Derivative Instruments	—		46		—		46		(14		)	32
Interest Rate Derivative Instruments	—		6		—		6		—			6
December 31, 2018
Assets:
Commodity Derivative Instruments	$	—	$	69	$	—	$	69	$	(14	)	$	55
Liabilities:
Commodity Derivative Instruments	—		25		—		25		(14		)	11

(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:

	March 31, 2019		December 31, 2018
	(In millions)
Current Assets: Prepaid assets and other	$	37	$	55
Total Assets	$	37	$	55
Current Liabilities: Other current liabilities	$	38	$	11
Total Liabilities	$	38	$	11

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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 March 31,
	2019			2018
	(In millions)
Realized gain (loss):
Derivative settlements, realized gain (loss)	$	15		$	(42	)
Amortization of put premium, realized loss	—			(5		)
Unrealized gain (loss)	(45		)	49
Derivative instrument gains (losses), net	$	(30	)	$	2

Derivative instrument gains and losses are recorded in “Derivative instrument gains (losses), net” under “Revenues and Other” in the Company’s statement of consolidated operations. Unrealized gains and losses for derivative activity recorded in the statement of consolidated operations are reflected in the statement of consolidated cash flows separately as “Unrealized derivative instrument gains (losses), net” in “Adjustments to reconcile net income (loss) to net cash provided by operating activities.”

5. EQUITY METHOD INTERESTS

Apache, through its ownership of Altus, consolidates the following equity method interests in Permian Basin pipelines. For each of the equity method interests, Altus has the ability to exercise significant influence based on certain governance provisions and its participation in the significant activities and decisions that impact the management and economic performance of the equity method interests.

	March 31, 2019				December 31, 2018
	Interest		Amount		Interest		Amount
	($ in millions)
Gulf Coast Express Pipeline LLC	15.0	%	$	157	15.0	%	$	91
EPIC Crude Holdings, LP	15.0	%	52		—		—
			$	209			$	91

The equity method interest balance as of March 31, 2019 and December 31, 2018 were $1 million and $6 million, respectively, less than Apache’s underlying equity in the separate net assets within the financial statements of the respective entities. Unamortized differences will be amortized into net income over the remaining useful lives of the associated pipelines, when they are placed into service.

The following table presents the activity in Apache’s equity method interests for the three months ended March 31, 2019:

	Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Total
	(In millions)
Balance at December 31, 2018	$	91	$	—	$	91
Acquisitions	—		52		52
Contributions	66		—		66
Balance at March 31, 2019	$	157	$	52	$	209

As of December 31, 2018, Apache also held an investment in Marine Well Containment Company. This investment was sold in the first quarter of 2019 for $30 million, with no gain or loss recorded on the sale.

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6. OTHER CURRENT LIABILITIES

The following table provides detail of the Company’s other current liabilities as of March 31, 2019 and December 31, 2018:

	March 31, 2019		December 31, 2018
	(In millions)
Accrued operating expenses	$	72	$	65
Accrued exploration and development	552		667
Accrued gathering, processing, and transmission - Altus	63		81
Accrued compensation and benefits	96		177
Accrued interest	121		137
Accrued income taxes	60		58
Current asset retirement obligation	66		66
Current operating lease liability	187		—
Other	139		90
Total other current liabilities	$	1,356	$	1,341

7. ASSET RETIREMENT OBLIGATION

The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the three-month period ended March 31, 2019:

	(In millions)
Asset retirement obligation at December 31, 2018	$	1,932
Liabilities incurred	3
Liabilities settled	(11		)
Liabilities held for sale	(6		)
Accretion expense	27
Asset retirement obligation at March 31, 2019	1,945
Less current portion	(66		)
Asset retirement obligation, long-term	$	1,879

8. INCOME TAXES

The Company estimates its annual effective income tax rate 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.

During the first quarter of 2019, Apache’s effective income tax rate was primarily impacted by an increase in the amount of valuation allowance against its U.S. deferred tax assets. During the first quarter of 2018, Apache’s effective income tax rate was also primarily impacted by an increase in the amount of valuation allowance against its U.S. 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. The Company is currently under IRS audit for the 2014-2016 tax years and is also under audit in various states and foreign jurisdictions as part of its normal course of business.

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9. DEBT AND FINANCING COSTS

The following table presents the carrying value of the Company’s debt as of March 31, 2019 and December 31, 2018:

	March 31, 2019			December 31, 2018
	(In millions)
Notes and debentures before unamortized discount and debt issuance costs	$	8,299		$	8,299
Commercial paper	159			—
Finance lease obligations	68			40
Unamortized discount	(43		)	(44		)
Debt issuance costs	(50		)	(51		)
Total debt	8,433			8,244
Current maturities	(339		)	(151		)
Long-term debt	$	8,094		$	8,093

As of March 31, 2019, current debt included $150 million of 7.625% senior notes due July 1, 2019, $159 million of commercial paper, and $30 million of finance lease obligations. As of December 31, 2018, current debt included $150 million of 7.625% senior notes due July 1, 2019 and $1 million of finance lease obligations.

The fair value of the Company’s notes and debentures was $8.3 billion and $7.8 billion as of March 31, 2019 and December 31, 2018, respectively. 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).

In March 2018, the Company entered into a revolving credit facility with commitments totaling $4.0 billion. In March 2019, the term of this facility was extended by one year to March 2024 (subject to Apache’s remaining one-year extension option) pursuant to Apache’s exercise of an extension option. The Company can increase commitments up to $5.0 billion by adding new lenders or obtaining the consent of any increasing existing lenders. The facility includes a letter of credit subfacility of up to $3.0 billion, of which $2.08 billion was committed as of March 31, 2019. The facility is for general corporate purposes, and committed borrowing capacity fully supports Apache’s commercial paper program. As of March 31, 2019, letters of credit aggregating approximately £3.1 million and no borrowings were outstanding under this facility.

The Company’s $3.5 billion commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of March 31, 2019, the Company had $159 million of commercial paper outstanding.

In November 2018, Altus Midstream LP, an indirectly controlled subsidiary of Apache, entered into a revolving credit facility for general corporate purposes that matures in November 2023 (subject to Altus Midstream LP’s two, one-year extension options). The agreement for this facility provides aggregate commitments from a syndicate of banks of $450 million until (i) the consolidated net income of Altus Midstream LP and its restricted subsidiaries, as adjusted pursuant to the agreement, for three consecutive calendar months equals or exceeds $175 million on an annualized basis and (ii) Altus Midstream LP has raised at least $250 million of additional capital (such period, the Initial Period). Following the Initial Period, the aggregate commitments equal $800 million. All aggregate commitments include a letter of credit subfacility of up to $100 million and a swingline loan subfacility of up to $100 million. After the Initial Period, Altus Midstream LP may increase commitments up to an aggregate $1.5 billion by adding new lenders or obtaining the consent of any increasing existing lenders. As of March 31, 2019, no borrowings or letters of credit were outstanding under this facility. The Altus Midstream LP credit facility is unsecured and is not guaranteed by Apache or any of Apache’s other subsidiaries.

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Financing Costs, Net

The following table presents the components of Apache’s financing costs, net:

	For the Quarter Ended March 31,
	2019			2018
	(In millions)
Interest expense	$	107		$	112
Amortization of deferred loan costs	2			5
Capitalized interest	(8		)	(12		)
Interest income	(4		)	(6		)
Financing costs, net	$	97		$	99

10. 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 March 31, 2019, the Company has an accrued liability of approximately $35 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 9—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, 2018.

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, 2018.

Louisiana Restoration 

As more fully described in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, Louisiana surface owners often file lawsuits or assert claims against oil and gas companies, including Apache, claiming that operators and working interest owners in the chain of title are liable for environmental damages on the leased premises, including damages measured by the cost of restoration of the leased premises to its original condition, regardless of the value of the underlying property. From time to time restoration lawsuits and claims are resolved by the Company for amounts that are not material to the Company, while new lawsuits and claims are asserted against the Company. With respect to each of the pending lawsuits and claims, the amount claimed is not currently determinable or is not material, except as noted. Further, the overall exposure related to these lawsuits and claims is not currently determinable. While an adverse judgment against Apache is possible, Apache intends to actively defend these lawsuits and claims.

Starting in November of 2013 and continuing into 2019, several parishes in Louisiana have pending lawsuits against many oil and gas producers, including Apache. These cases have all been removed to federal 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 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.

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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, 2018.

Apollo Exploration Lawsuit

In a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation, Cause No. CV50538 in the 385th Judicial District Court, Midland County, Texas, plaintiffs alleged damages in excess of $200 million (having previously claimed in excess of $1.1 billion) relating to 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 motions filed by Apache reducing the plaintiffs’ alleged damages to an amount that is not material to the Company. Apache believes that plaintiffs’ claims lack merit and 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, 2018.

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 Quadrant Energy Pty Ltd (Quadrant). Closing occurred on June 5, 2015. In April 2017, Apache filed suit against Quadrant for breach of the SPA. In its suit, Apache seeks approximately $80 million. In December 2017, Quadrant filed a defense of equitable set-off to Apache’s claim and a counterclaim seeking approximately $200 million in the aggregate. The Company believes that Quadrant’s claims lack merit and will not have a material adverse effect on the Company’s financial position, results of operation, or liquidity.

California Litigation

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. On December 20, 2017, in two separate actions, the City of Santa Cruz and Santa Cruz County and in a separate action on January 22, 2018, the City of Richmond, filed similar lawsuits against many of the same defendants. On November 14, 2018, the Pacific Coast Federation of Fishermen’s Associations, Inc. also filed a similar lawsuit against many of the same defendants. Apache believes that the claims made against it are baseless and intends to vigorously defend these lawsuits.

Castex Lawsuit

In a case styled Apache Corporation v. Castex Offshore, Inc, et. al., Cause No. 2015-48580, in the 113rd Judicial District Court of Harris County, Texas, Castex filed claims for alleged damages which they recently disclosed to be approximately $200 million, relating to overspend on the Belle Isle Gas Facility upgrade, and the drilling of five sidetracks on the Potomac #3 Well. After a jury trial, a verdict of approximately $60 million was entered against Apache. Apache intends to appeal.

Environmental Matters

As of March 31, 2019, the Company had an undiscounted reserve for environmental remediation of approximately $5 million. The Company is not aware of any environmental claims existing as of March 31, 2019, 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.

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11. 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 ended March 31, 2019 and 2018, is presented in the table below.

 

	For the Quarter Ended March 31,
	2019							2018
	Loss			Shares	Per Share			Income		Shares	Per Share
	(In millions, except per share amounts)
Basic:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	382	$	0.38
Effect of Dilutive Securities:
Stock options and other	$	—		—	$	—		$	—	2	$	—
Diluted:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	384	$	0.38

The diluted earnings per share calculation excludes options and restricted stock units that were anti-dilutive totaling 5.5 million and 6.7 million for the quarters ended March 31, 2019 and 2018, respectively.

Common Stock Dividends

For the quarters ended March 31, 2019, and 2018, Apache paid $94 million and $95 million, respectively, in dividends on its common stock.

Stock Repurchase Program

In 2013 and 2014, Apache’s Board of Directors authorized the purchase of up to 40 million shares of the Company’s common stock. Shares may be purchased from time to time either in the open market or through privately negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through March 31, 2019, had repurchased a total of 40 million shares at an average price of $79.18 per share. During the fourth quarter of 2018, the Company’s Board of Directors authorized the purchase of up to 40 million additional shares of the Company’s common stock. The Company is not obligated to acquire any specific number of shares and has not purchased any shares during 2019.

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12. BUSINESS SEGMENT INFORMATION

As of March 31, 2019, Apache is engaged in exploration and production (Upstream) activities across three operating segments: Egypt, the North Sea, and the U.S. Apache also has exploration interests in Suriname that may, over time, result in a reportable discovery and development opportunity. Apache’s Upstream business explores for, develops, and produces natural gas, crude oil and natural gas liquids. During the fourth quarter of 2018, Apache established a new reporting segment for its U.S. midstream business separate from its upstream oil and gas development activities. The midstream business is operated by Altus, which owns, develops, and operates a midstream energy asset network in the Permian Basin of West Texas, anchored by midstream service contracts to Apache’s production from its Alpine High resource play. Altus primarily generates revenue by providing fee-based natural gas gathering, compression, processing, and transportation services. Financial information for each segment is presented below:

	Egypt(1)		North Sea		U.S.		Altus		Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2019
Oil revenues	$	514	$	300	$	496	$	—	$	—		$	1,310
Natural gas revenues	81		32		123		—		—			236
Natural gas liquids revenues	4		6		98		—		—			108
Oil and gas production revenues	599		338		717		—		—			1,654
Midstream service affiliate revenues	—		—		—		34		(34		)	—
Operating Expenses:
Lease operating expenses	118		72		176		—		(1		)	365
Gathering, processing, and transmission	12		12		81		16		(33		)	88
Taxes other than income	—		—		48		3		—			51
Exploration	32		1		33		—		3			69
Depreciation, depletion, and amortization	188		99		352		7		—			646
Asset retirement obligation accretion	—		19		8		—		—			27
	350		203		698		26		(31		)	1,246
Operating Income (Loss)(3)	$	249	$	135	$	19	$	8	$	(3	)	408
Other Income (Expense):
Gain on divestitures												3
Derivative instrument losses, net												(30		)
Other(4)												8
General and administrative												(123		)
Transaction, reorganization, and separation												(4		)
Financing costs, net												(97		)
Income Before Income Taxes												$	165
Total Assets(5)	$	4,065	$	2,601	$	13,205	$	1,825	$	55		$	21,751

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	Egypt(1)		North Sea		U.S.		Altus			Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2018
Oil revenues	$	569	$	271	$	553	$	—		$	—		$	1,393
Natural gas revenues	88		24		110		—			—			222
Natural gas liquids revenues	3		4		111		—			—			118
Oil and gas production revenues	660		299		774		—			—			1,733
Midstream service affiliate revenues	—		—		—		12			(12		)	—
Operating Expenses:
Lease operating expenses	98		93		158		—			—			349
Gathering, processing, and transmission	12		10		65		11			(12		)	86
Taxes other than income	—		—		52		3			—			55
Exploration	28		14		33		—			1			76
Depreciation, depletion, and amortization	186		95		269		3			—			553
Asset retirement obligation accretion	—		19		8		—			—			27
	324		231		585		17			(11		)	1,146
Operating Income (Loss)(3)	$	336	$	68	$	189	$	(5	)	$	(1	)	587
Other Income (Expense):
Gain on divestitures													7
Derivative instrument gains, net													2
Other(4)													5
General and administrative													(114		)
Financing costs, net													(99		)
Income Before Income Taxes													$	388
Total Assets(5)	$	4,813	$	3,009	$	13,106	$	821		$	42		$	21,791

(1) Includes revenue from non-customers of $107 million, $11 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2019, and $139 million, $15 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2018.

(2) Includes a noncontrolling interest in Egypt for the 2019 and 2018 periods, and Altus for the 2019 period.

(3) The operating income of U.S. and North Sea includes leasehold and unproved impairments totaling $21 million and $2 million, respectively, for the first quarter of 2019. The operating income of U.S. includes leasehold and unproved impairments totaling $16 million for the first quarter of 2018.

(4) Included in Other are sales proceeds related to U.S. third-party purchased oil and gas totaling $24 million and $104 million for the periods ending March 31, 2019 and 2018, respectively, which are determined to be revenue from customers.

(5) Intercompany balances are excluded from total assets.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion relates to Apache Corporation and its consolidated subsidiaries and should be read in conjunction with the Company’s consolidated financial statements and accompanying notes included under Part I, Item 1, “Financial Statements” of this Quarterly Report on Form 10-Q, as well as the Company’s consolidated financial statements, accompanying notes and Management’s Discussion and Analysis of Financial Condition and Results of Operations included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018.

Overview

Apache Corporation, a Delaware corporation formed in 1954, is an independent energy company that explores for, develops, and produces natural gas, crude oil, and natural gas liquids. The Company’s upstream business currently has exploration and production operations in three geographic areas: the United States (U.S.), Egypt, and offshore the United Kingdom (U.K.) 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. Apache’s midstream business is operated by Altus Midstream Company through its subsidiary Altus Midstream LP (collectively, Altus), which owns, develops, and operates a midstream energy asset network in the Permian Basin of West Texas, anchored by midstream service contracts to Apache’s production from its Alpine High resource play. Altus primarily generates revenue by providing fee-based natural gas gathering, compression, processing, and transportation services.

Apache reported a first quarter loss of $47 million, or $0.12 per common share, compared to income of $145 million, or $0.38 per common share, in the first quarter of 2018. The decrease in net income compared to the prior-year quarter is primarily the result of lower commodity price realizations. Daily production in the first quarter of 2019 averaged 503 Mboe/d, an increase of 14 percent from the comparative prior-year quarter driven primarily by activity in the Permian Basin, including continued development of the Company’s Alpine High field. Apache’s U.S. assets are complemented by its international assets in Egypt and the North Sea, each of which adds to the Company’s deep inventory of exploration and development opportunities and generates cash flows in excess of current capital investments, facilitating the Company’s ability to develop Alpine High while maintaining financial flexibility.

The Company generated $598 million in cash from operating activities during the quarter, a decrease of 3 percent from the first quarter of last year, driven by lower revenues from lower realized commodity prices. Apache ended the quarter with $327 million of cash. Apache continuously monitors changes in its operating environment and has the ability, with its dynamic capital allocation process, to adjust the Company’s capital investment program to levels commensurate with cash from operating activities and to maximize value for Apache’s shareholders over the long term. In light of the lower commodity price environment at the end of 2018, Apache curtailed its 2019 upstream development program, with capital costs incurred for the first quarter of 2019 reflecting a 26 percent reduction from the fourth quarter of 2018 and a 19 percent reduction from the first quarter of 2018.

Operating Highlights

Key operational highlights for the quarter include:

United States

• U.S. onshore equivalent production increased 27 percent from the first quarter of 2018, a reflection of the success of the Midland Basin drilling program and the commencement and continued production ramp-up at Alpine High.

• First quarter equivalent production from the Permian region, which accounts for 85 percent of Apache’s total U.S. production, increased 36 percent from the first quarter of 2018, which was driven by continued production ramp-up at Alpine High and strong performance in the Midland Basin.

International

• The Egypt region averaged 10 rigs and drilled 23 gross wells during the first quarter of 2019. Gross equivalent production increased 1 percent from the first quarter of 2018; however, net production decreased 5 percent due to the impact of lower recoverable costs on volumes as a result of the mechanics of the Company’s production sharing contracts. The region contributed $599 million of revenues during the first quarter of 2019.

• The North Sea region averaged 3 rigs and drilled 5 gross wells during the first quarter of 2019. The region’s daily production increased 21 percent from the first quarter 2018, primarily the result of a development well coming online at the Callater field, production from the Garten field which came online in November 2018, and less downtime at the Beryl field as compared to the prior-year quarter.

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• The Company continues to progress its exploration efforts in Suriname. Apache will drill its first well on the 100 percent-owned Black 58 this year, extending the concession term through June 30, 2022. A drillship has been contracted, and the Company anticipates spudding the well around mid-year.

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Results of Operations

Oil and Gas Revenues

The table below presents revenues by geographic region and each region’s percent contribution to revenues for the first quarters of 2019 and 2018.

	For the Quarter Ended March 31,
	2019				2018
	$ Value		% Contribution		$ Value		% Contribution
	($ in millions)
Total Oil Revenues:
United States	$	496	38	%	$	553	40	%
Egypt (1)	514		39	%	569		41	%
North Sea	300		23	%	271		19	%
Total (1)	$	1,310	100	%	$	1,393	100	%
Total Natural Gas Revenues:
United States	$	123	52	%	$	110	49	%
Egypt (1)	81		34	%	88		40	%
North Sea	32		14	%	24		11	%
Total (1)	$	236	100	%	$	222	100	%
Total Natural Gas Liquids (NGL) Revenues:
United States	$	98	91	%	$	111	94	%
Egypt (1)	4		4	%	3		3	%
North Sea	6		5	%	4		3	%
Total (1)	$	108	100	%	$	118	100	%
Total Oil and Gas Revenues:
United States	$	717	43	%	$	774	45	%
Egypt (1)	599		36	%	660		38	%
North Sea	338		21	%	299		17	%
Total (1)	$	1,654	100	%	$	1,733	100	%

(1) Includes revenues attributable to a noncontrolling interest in Egypt.

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Production

The table below presents the first-quarter 2019 and 2018 production and the relative increase or decrease from the prior period.

	For the Quarter Ended March 31,
	2019	Increase (Decrease)		2018
Oil Volume – b/d
United States	108,778	9	%	99,747
Egypt(1)(2)	91,616	(4	)%	95,270
North Sea	54,528	18	%	46,348
Total	254,922	6	%	241,365
Natural Gas Volume – Mcf/d
United States	744,307	52	%	488,544
Egypt(1)(2)	315,508	(8	)%	343,901
North Sea	56,892	39	%	41,039
Total	1,116,707	28	%	873,484
NGL Volume – b/d
United States	58,864	15	%	51,284
Egypt(1)(2)	1,150	23	%	937
North Sea	1,823	56	%	1,168
Total	61,837	16	%	53,389
BOE per day(3)
United States	291,693	25	%	232,456
Egypt(1)(2)	145,351	(5	)%	153,524
North Sea(4)	65,833	21	%	54,356
Total	502,877	14	%	440,336

(1) Gross oil, natural gas, and NGL production in Egypt for the first quarter of 2019 and 2018 were as follows:

	For the Quarter Ended March 31,
	2019	2018
Oil (b/d)	203,985	202,209
Natural Gas (Mcf/d)	755,715	758,275
NGL (b/d)	2,065	1,475

(2) Includes production volumes per day attributable to a noncontrolling interest in Egypt for the first quarter of 2019 and 2018 of:

	For the Quarter Ended March 31,
	2019	2018
Oil (b/d)	30,554	31,774
Natural Gas (Mcf/d)	105,412	114,913
NGL (b/d)	383	312

(3) The table shows production on a barrel of oil equivalent basis (boe) in which natural gas is converted to an equivalent barrel of oil based on a 6:1 energy equivalent ratio. This ratio is not reflective of the price ratio between the two products.

(4) Average sales volumes from the North Sea for the first quarter of 2019 and 2018 were 63,176 boe/d and 53,695 boe/d, respectively. Sales volumes may vary from production volumes as a result of the timing of liftings in the Beryl field.

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Pricing

The table below presents first-quarter 2019 and 2018 pricing and the relative increase or decrease from the prior period.

 

	For the Quarter Ended March 31,
	2019		Increase (Decrease)		2018
Average Oil Price - Per barrel
United States	$	50.70	(18	)%	$	61.76
Egypt	62.35		(6	)%	66.30
North Sea	64.15		(3	)%	65.87
Total	57.70		(10	)%	64.34
Average Natural Gas Price - Per Mcf
United States	$	1.83	(27	)%	$	2.49
Egypt	2.85		—		2.85
North Sea	6.24		(5	)%	6.60
Total	2.34		(17	)%	2.82
Average NGL Price - Per barrel
United States	$	18.47	(23	)%	$	24.02
Egypt	37.66		4	%	36.19
North Sea	40.60		(5	)%	42.82
Total	19.49		(21	)%	24.65

Crude Oil Revenues Crude oil revenues for the first quarter of 2019 totaled $1.3 billion, an $83 million decrease from the comparative 2018 quarter. A 6 percent increase in average daily production increased first-quarter 2019 revenues by $61 million compared to the prior-year quarter, while 10 percent lower average realized prices decreased revenues by $144 million. Crude oil accounted for 79 percent of oil and gas production revenues and 51 percent of worldwide production in the first quarter of 2019. Crude oil prices realized in the first quarter of 2019 averaged $57.70 per barrel, compared with $64.34 per barrel in the comparative prior-year quarter.

Worldwide oil production increased 13.6 Mb/d to 254.9 Mb/d in the first quarter of 2019 from the comparative prior-year period, primarily a result of an increase in the Permian region on the success of the Midland Basin drilling program and an increase in the North Sea from the Garten field coming online in November 2018.

Natural Gas Revenues Gas revenues for the first quarter of 2019 totaled $236 million, a $14 million increase from the comparative 2018 quarter. A 28 percent increase in average daily production increased first-quarter revenues by $51 million compared to the prior-year quarter, while 17 percent lower average realized prices decreased revenues by $37 million. Natural gas accounted for 14 percent of Apache’s oil and gas production revenues and 37 percent of its equivalent production during the first quarter of 2019.

Worldwide natural gas production increased 243 MMcf/d to 1.1 Bcf/d in the first quarter of 2019 from the comparative prior-year period, primarily a result of the Alpine High development.

NGL Revenues NGL revenues for the first quarter of 2019 totaled $108 million, a $10 million decrease from the comparative 2018 quarter. A 16 percent increase in average daily production increased first-quarter 2019 revenues by approximately $15 million compared to the prior-year quarter, while 21 percent lower average realized prices decreased revenues by $25 million. NGLs accounted for 7 percent of Apache’s oil and gas production revenues and 12 percent of its equivalent production during the first quarter of 2019.

Worldwide production of NGLs increased 8.4 Mb/d to 61.8 Mb/d in the first quarter of 2019 from the comparative prior-year period, primarily a result of the Alpine High development.

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Altus Revenues

During the first quarter of 2019 and 2018, midstream services revenues totaling $34 million and $12 million, respectively, were generated through fee-based contractual arrangements between Apache and Altus and eliminated upon consolidation. The increase was primarily driven by higher throughput volumes from Alpine High.

Operating Expenses

The table below presents a comparison of the Company’s expenses on an absolute dollar basis. The Company’s discussion may reference expenses on a boe basis, on an absolute dollar basis or both, depending on context. All operating expenses include costs attributable to a noncontrolling interest in Altus and Egypt.

	For the Quarter Ended March 31,
	2019		2018
	(In millions)
Lease operating expenses	$	365	$	349
Gathering, processing, and transmission	88		86
Taxes other than income	51		55
Exploration	69		76
General and administrative	123		114
Transaction, reorganization, and separation	4		—
Depreciation, depletion, and amortization:
Oil and gas property and equipment	607		518
GPT assets	23		19
Other assets	16		16
Asset retirement obligation accretion	27		27
Financing costs, net	97		99

Lease Operating Expenses (LOE) LOE increased $16 million, or 5 percent, for the first quarter of 2019 on an absolute dollar basis relative to the comparable period of 2018. On a per-unit basis, LOE decreased 8 percent to $8.12 per boe for the first quarter of 2019 compared to the prior-year period. The decrease on a per-unit basis is primarily the result of lower average operating costs and an increase in volumes primarily from Alpine High.

Gathering, Processing, and Transmission (GPT) GPT expenses include transmission and processing costs paid to third-party carriers and to Altus for Apache’s upstream oil and gas production. GPT expenses also include midstream operating costs incurred by Altus. The following table presents a summary of these expenses:

	For the Quarter Ended March 31,
	2019			2018
	(In millions)
Third-party processing and transmission costs	$	72		$	75
Midstream service affiliate costs	33			12
Upstream processing and transmission costs	105			87
Midstream operating expenses	16			11
Intersegment eliminations	(33		)	(12		)
Total GPT costs	$	88		$	86

GPT costs remained relatively flat compared with the first quarter of 2018. Midstream service affiliate costs increased $21 million as a result of increased Alpine High volumes. These costs are eliminated upon consolidation.

Taxes other than Income Taxes other than income totaled $51 million for the first quarter of 2019, a decrease of $4 million from the first quarter of 2018, primarily the result of a $4 million decrease in severance taxes on lower commodity prices.

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Exploration Expense Exploration expense includes unproved leasehold impairments, exploration dry hole expense, geological and geophysical expenses, and the costs of maintaining and retaining unproved leasehold properties. Exploration expenses in the first quarter of 2019 decreased $7 million compared to the prior-year period.

The following table presents a summary of exploration expense:

	For the Quarter Ended March 31,
	2019		2018
	(In millions)
Unproved leasehold impairments	$	23	$	16
Dry hole expense	10		20
Geological and geophysical expense	19		18
Exploration overhead and other	17		22
	$	69	$	76

Unproved leasehold impairments increased $7 million from the first quarter of 2018, primarily a result of a decrease in planned activity on term acreage. Dry hole expense decreased $10 million in the first quarter from the prior-year quarter, a result of unsuccessful international offshore exploration in the 2018 period.

General and Administrative (G&A) Expenses G&A expense for the first quarter of 2019 was $9 million higher than the comparative 2018 period. The increase in G&A expense was primarily related to higher incentive and stock-based compensation.

Transaction, Reorganization, and Separation (TRS) Costs The Company recorded $4 million of expenses during the first quarter of 2019, primarily related to company reorganization, including separation costs and other associated costs. The Company recorded no TRS costs in the first quarter of 2018.

Depreciation, Depletion, and Amortization (DD&A) Oil and gas property DD&A expense increased $89 million compared to the first quarter of 2018, over 80 percent of which was a result of higher production. The Company’s oil and gas property DD&A rate increased 3 percent or $0.39 per boe in the first quarter of 2019 compared to the comparable prior-year period. GPT depreciation increased $4 million compared to the prior-year period, primarily a result of capital spending on Altus infrastructure. Other asset depreciation remained flat compared with the first quarter of 2018.

Impairments The Company did not record any asset impairments in connection with fair value assessments in each of the first quarters of 2019 and 2018. For more information regarding asset impairments, please refer to “Fair Value Measurements” and “Oil and Gas Property” within Note 1—Summary of Significant Accounting Policies in the Notes to Consolidated Financial Statements in Part 1, Item 1 of this Quarterly Report on Form 10-Q.

Financing Costs, Net Financing costs incurred during the period comprised the following:

	For the Quarter Ended March 31,
	2019			2018
	(In millions)
Interest expense	$	107		$	112
Amortization of deferred loan costs	2			5
Capitalized interest	(8		)	(12		)
Interest income	(4		)	(6		)
Financing costs, net	$	97		$	99

Net financing costs remained relatively flat compared with the first quarter of 2018. Interest expense decreased $5 million compared to the comparable prior-year period as a result of the Company’s debt refinancing in the fourth quarter of 2018.

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Provision for Income Taxes The Company estimates its annual effective income tax rate 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.

During the first quarter of 2019, Apache’s effective income tax rate was primarily impacted by an increase in the amount of valuation allowance against its U.S. deferred tax assets. During the first quarter of 2018, Apache’s effective income tax rate was also primarily impacted by an increase in the amount of valuation allowance against its U.S. deferred tax assets.

The Company continues to record a full valuation allowance against its U.S. net deferred tax assets and will continue to maintain a full valuation allowance until there is sufficient evidence to support the reversal of all or some portion of this allowance.

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. The Company is currently under IRS audit for the 2014-2016 tax years and is also under audit in various states and foreign jurisdictions as part of its normal course of business.

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Capital Resources and Liquidity

Operating cash flows are the Company’s primary source of liquidity. The Company may also elect to utilize available cash on hand, committed borrowing capacity, access to both debt and equity capital markets, or proceeds from the sale of nonstrategic assets for all other liquidity and capital resource needs.

Apache’s operating cash flows, both in the short-term and the long-term, are impacted by highly volatile oil and natural gas prices, as well as costs and sales volumes. Significant changes in commodity prices impact Apache’s revenues, earnings, and cash flows. These changes potentially impact Apache’s liquidity if costs do not trend with changes in commodity prices. Historically, costs have trended with commodity prices, albeit on a lag. Sales volumes also impact cash flows; however, they have a less volatile impact in the short term.

Apache’s long-term operating cash flows are dependent on reserve replacement and the level of costs required for ongoing operations. Cash investments are required to fund activity necessary to offset the inherent declines in production and proved crude oil and natural gas reserves. Future success in maintaining and growing reserves and production is highly dependent on the success of Apache’s drilling program and its ability to add reserves economically. Changes in commodity prices also impact estimated quantities of proved reserves.

Apache believes the liquidity and capital resource alternatives available to the Company, combined with proactive measures to adjust its capital budget to reflect volatile commodity prices and anticipated operating cash flows, will be adequate to fund short-term and long-term operations, including Apache’s capital development program, repayment of debt maturities, payment of dividends, and any amount that may ultimately be paid in connection with commitments and contingencies.

For additional information, please see Part I, Items 1 and 2, “Business and Properties,” and Item 1A, “Risk Factors,” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018.

Sources and Uses of Cash

The following table presents the sources and uses of the Company’s cash and cash equivalents for the periods presented.

	For the Three Months Ended March 31,
	2019			2018
	(In millions)
Sources of Cash and Cash Equivalents:
Net cash provided by operating activities	$	598		$	615
Proceeds from sale of oil and gas properties	9			9
Commercial paper	159			—
Other	29			—
	795			624
Uses of Cash and Cash Equivalents:
Capital expenditures(1)	$	848		$	865
Leasehold and property acquisitions	15			12
Altus equity method interests	118			—
Payments on fixed-rate debt	—			150
Dividends paid	94			95
Distributions to noncontrolling interest - Egypt	107			69
Other	—			24
	1,182			1,215
Decrease in cash and cash equivalents	$	(387	)	$	(591	)

(1) The table presents capital expenditures on a cash basis; therefore, the amounts may differ from those discussed elsewhere in this document, which include accruals.

Net Cash Provided by Operating Activities Operating cash flows are Apache’s primary source of capital and liquidity and are impacted, both in the short term and the long term, by volatile oil and natural gas prices. The factors that determine operating cash flows are largely the same as those that affect net earnings, with the exception of non-cash expenses such as DD&A, exploratory dry hole expense, asset impairments, asset retirement obligation (ARO) accretion, and deferred income tax expense.

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Net cash provided by operating activities for the first three months of 2019 totaled $598 million, a decrease of $17 million from the first three months of 2018. The decrease primarily reflects lower commodity prices compared to the prior-year period, partially offset by higher production volumes.

For a detailed discussion of commodity prices, production, and expenses, refer to the “Results of Operations” of this Item 2. For additional detail on the changes in operating assets and liabilities and the non-cash expenses that do not impact net cash provided by operating activities, please see the statement of consolidated cash flows in Part I, Item 1, Financial Statements of this Quarterly Report on Form 10-Q.

Asset Divestitures The Company recorded proceeds from non-core asset divestitures, primarily in the Permian region, totaling $9 million in each of the first three months of 2019 and 2018. For more information regarding the Company’s acquisitions and divestitures, please see Note 2—Acquisitions and Divestitures in the Notes to Consolidated Financial Statements in Part 1, Item 1 of this Quarterly Report on Form 10-Q.

Capital Expenditures Worldwide exploration and development (E&D) cash expenditures for the first three months of 2019 totaled $729 million, compared to $737 million for the first three months of 2018. Expenditures were primarily in the Permian region as Apache continues development of its Alpine High play. Apache operated an average of 29 drilling rigs during the first quarter of 2019.

Apache’s cash expenditures in GPT facilities totaled $119 million and $128 million in the first three months of 2019 and 2018, respectively, and are nearly all comprised investments in midstream infrastructure for the Alpine High play, which were contributed to Altus Midstream LP upon closing of the Altus transaction in the fourth quarter of 2018.

Apache also completed leasehold and property acquisitions for cash totaling $15 million and $12 million during the first three months of 2019 and 2018, respectively. Acquisition investments continued to focus on adding new leasehold positions to the Company’s U.S. onshore regions.

Altus Equity Method Interests Apache made acquisitions and contributions in its equity method interests of $118 million in the first three months of 2019. The Company had no equity method interest cash activity in the first three months of 2018. For more information regarding the Company’s equity method interests, please see Note 5—Equity Method Interests in the Notes to Consolidated Financial Statements in Part 1, Item 1 of this Quarterly Report on Form 10-Q.

Dividends For the three-month periods ended March 31, 2019 and 2018, the Company paid $94 million and $95 million, respectively, in dividends on its common stock.

Egypt Noncontrolling Interest Sinopec International Petroleum Exploration and Production Corporation (Sinopec) holds a one-third minority participation interest in Apache’s oil and gas business in Egypt. Apache made cash distributions totaling $107 million and $69 million to Sinopec in the first three months of 2019 and 2018, respectively.

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Liquidity

The following table presents a summary of the Company’s key financial indicators at the dates presented:

	March 31, 2019		December 31, 2018
	(In millions)
Cash and cash equivalents	$	327	$	714
Total debt	8,433		8,244
Equity	8,609		8,812
Available committed borrowing capacity	3,837		3,857
Available committed borrowing capacity - Altus	450		450

Cash and cash equivalents The Company had $327 million in cash and cash equivalents as of March 31, 2019, of which approximately $177 million was held by Altus. The majority of the cash is invested in highly liquid, investment grade securities with maturities of three months or less at the time of purchase.

Debt As of March 31, 2019, outstanding debt, which consisted of notes, debentures and finance lease obligations, totaled $8.4 billion. Current debt as of March 31, 2019, included $150 million of 7.625% senior notes due July 1, 2019, $159 million of commercial paper, and $30 million of finance lease obligations.

In March 2018, the Company entered into a revolving credit facility with commitments totaling $4.0 billion. In March 2019, the term of this facility was extended by one year to March 2024 (subject to Apache’s remaining one-year extension option) pursuant to Apache’s exercise of an extension option. The Company can increase commitments up to $5.0 billion by adding new lenders or obtaining the consent of any increasing existing lenders. The facility includes a letter of credit subfacility of up to $3.0 billion, of which $2.08 billion was committed as of March 31, 2019. The facility is for general corporate purposes, and committed borrowing capacity fully supports Apache’s commercial paper program. As of March 31, 2019, letters of credit aggregating approximately £3.1 million and no borrowings were outstanding under this facility.

The Company’s $3.5 billion commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of March 31, 2019, the Company had $159 million of commercial paper outstanding.

In November 2018, Altus Midstream LP, an indirectly controlled subsidiary of Apache, entered into a revolving credit facility for general corporate purposes that matures in November 2023 (subject to Altus Midstream LP’s two, one-year extension options). The agreement for this facility provides aggregate commitments from a syndicate of banks of $450 million until (i) the consolidated net income of Altus Midstream LP and its restricted subsidiaries, as adjusted pursuant to the agreement, for three consecutive calendar months equals or exceeds $175 million on an annualized basis and (ii) Altus Midstream LP has raised at least $250 million of additional capital (such period, the Initial Period). Following the Initial Period, the aggregate commitments equal $800 million. All aggregate commitments include a letter of credit subfacility of up to $100 million and a swingline loan subfacility of up to $100 million. After the Initial Period, Altus Midstream LP may increase commitments up to an aggregate $1.5 billion by adding new lenders or obtaining the consent of any increasing existing lenders. As of March 31, 2019, no borrowings or letters of credit were outstanding under this facility. The Altus Midstream LP credit facility is unsecured and is not guaranteed by Apache or any of Apache’s other subsidiaries.

The Company was in compliance with the terms of its credit facilities as of March 31, 2019.

Off-Balance Sheet Arrangements Apache enters into customary agreements in the oil and gas industry for drilling rig commitments, firm transportation agreements, and other obligations as described in “Contractual Obligations” in Item 7, Part II of the Form 10-K for the year ended December 31, 2018. There have been no material changes to the contractual obligations described therein.

31

ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Risk

The Company’s revenues, earnings, cash flow, capital investments and, ultimately, future rate of growth are highly dependent on the prices the Company receives for its crude oil, natural gas, and NGLs, which have historically been very volatile because of unpredictable events such as economic growth or retraction, weather, political climate, and global supply and demand. The Company’s average crude oil realizations have decreased 10 percent to $57.70 per barrel in the first quarter of 2019 from $64.34 per barrel in the comparable period of 2018. The Company’s average natural gas price realizations have decreased 17 percent to $2.34 per Mcf in the first quarter of 2019 from $2.82 per Mcf in the comparable period of 2018. Based on average daily production for the first quarter of 2019, a $1.00 per barrel change in the weighted average realized oil price would have increased or decreased revenues for the quarter by approximately $23 million, and a $0.10 per Mcf change in the weighted average realized price of natural gas would have increased or decreased revenues for the quarter by approximately $10 million.

Apache periodically enters into derivative positions on a portion of its projected oil and natural gas production through a variety of financial and physical arrangements intended to manage fluctuations in cash flows resulting from changes in commodity prices. Apache periodically uses futures contracts, swaps, and options to mitigate commodity price risk. Apache does not hold or issue derivative instruments for trading purposes. As of March 31, 2019, the Company had open natural gas derivatives not designated as cash flow hedges in an asset position with a fair value of $49 million. A 10 percent increase in gas prices would increase the asset by approximately $4 million, while a 10 percent decrease in prices would decrease the asset by approximately $3 million. As of March 31, 2019, the Company had open oil derivatives not designated as cash flow hedges in a liability position with a fair value of $45 million. A 10 percent increase in oil prices would increase the liability by approximately $32 million, while a 10 percent decrease in prices would decrease the liability by approximately $32 million. These fair value changes assume volatility based on prevailing market parameters at March 31, 2019. See Note 4—Derivative Instruments and Hedging Activities in the Notes to Consolidated Financial Statements set forth in Part I, Item 1 of this Quarterly Report on Form 10-Q for notional volumes and terms with the Company’s derivative contracts.

Interest Rate Risk

At March 31, 2019, Apache had approximately $8.1 billion of long-term debt (excluding capital lease and other obligations) outstanding, all of which was fixed-rate debt, with a weighted average interest rate of 4.85 percent. Although near-term changes in interest rates may affect the fair value of Apache’s fixed-rate debt, they do not expose the Company to the risk of earnings or cash flow loss associated with that debt. Apache is also exposed to interest rate risk related to its interest-bearing cash and cash equivalents balances and amounts outstanding under its commercial paper program and credit facilities. As of March 31, 2019, the Company’s cash and cash equivalents totaled approximately $327 million, approximately 94 percent of which was invested in money market funds and short-term investments with major financial institutions. A change in the interest rate applicable to the Company’s short-term investments would have a de minimis impact on earnings and cash flows but could impact interest costs associated with future debt issuances or any future borrowings under its commercial paper program, revolving credit facilities, and money market lines of credit. Apache currently has $400 million of U.S. treasury locks outstanding in order to minimize exposure to variability in interest rates associated with potential issuances of debt.

Foreign Currency Risk

The Company’s cash activities relating to certain international operations is based on the U.S. dollar equivalent of cash flows measured in foreign currencies. The Company’s North Sea production is sold under U.S. dollar contracts, and the majority of costs incurred are paid in British pounds. In Egypt, substantially all oil and gas production is sold under U.S. dollar contracts, and the majority of the costs incurred are denominated in U.S. dollars. Transactions denominated in British pounds are converted to U.S. dollar equivalents based on average exchange rates during the period.

Foreign currency gains and losses also arise when monetary assets and monetary liabilities denominated in foreign currencies are translated at the end of each month. Currency gains and losses are included as either a component of “Other” under “Revenues and Other” or, as is the case when the Company re-measures its foreign tax liabilities, as a component of the Company’s provision for income tax expense on the statement of consolidated operations. A foreign currency net gain or loss of $3 million would result from a 10 percent weakening or strengthening, respectively, in the British pound as of March 31, 2019.

The Company has outstanding foreign exchange contracts with a total notional amount of £113 million that are used to reduce its exposure to fluctuating foreign exchange rates for the British pound. A 10 percent strengthening of the British pound against the U.S. dollar would result in a foreign currency net gain of $12 million, while a 10 percent weakening of the British pound against the U.S. dollar would result in a loss of $3 million.

32

ITEM 4 – CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

John J. Christmann IV, the Company’s Chief Executive Officer and President, in his capacity as principal executive officer, and Stephen J. Riney, the Company’s Executive Vice President and Chief Financial Officer, in his capacity as principal financial officer, evaluated the effectiveness of our disclosure controls and procedures as of March 31, 2019, the end of the period covered by this report. Based on that evaluation and as of the date of that evaluation, these officers concluded that the Company’s disclosure controls and procedures were effective, providing effective means to ensure that information we are required to disclose under applicable laws and regulations is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.

We periodically review the design and effectiveness of our disclosure controls, including compliance with various laws and regulations that apply to our operations both inside and outside the United States. We make modifications to improve the design and effectiveness of our disclosure controls, and may take other corrective action, if our reviews identify deficiencies or weaknesses in our controls.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the quarter ended March 31, 2019 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

33

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Please refer to Part I, Item 3 of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 (filed with the SEC on February 28, 2019) and Note 10—Commitments and Contingencies in the notes to the consolidated financial statements set forth in Part I, Item 1 of this Quarterly Report on Form 10-Q, for a description of material legal proceedings.

ITEM 1A. RISK FACTORS

Please refer to Part I, Item 1A—Risk Factors of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, and Part I, Item 3—Quantitative and Qualitative Disclosures About Market Risk of this Quarterly Report on Form 10-Q. There have been no material changes to our risk factors since our annual report on Form 10-K for the fiscal year ended December 31, 2018.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

In 2013 and 2014, Apache’s Board of Directors authorized the purchase of up to 40 million shares of the Company’s common stock. Shares may be purchased from time to time either in the open market or through privately negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through March 31, 2019, had repurchased a total of 40 million shares at an average price of $79.18 per share. During the fourth quarter of 2018, the Company’s Board of Directors authorized the purchase of up to 40 million additional shares of the Company’s common stock. The Company is not obligated to acquire any specific number of shares and has not purchased any shares during 2019.

ITEM 6. EXHIBITS

3.1	–	Restated Certificate of Incorporation of Registrant, dated September 19, 2013, as filed with the Secretary of State of Delaware on September 19, 2013 (incorporated by reference to Exhibit 3.2 to Registrant’s Current Report on Form 8-K filed September 20, 2013, SEC File No. 001-4300).
3.2	–	Certificate of Amendment of Restated Certificate of Incorporation of Registrant, dated May 14, 2015, as filed with the Secretary of State of Delaware on May 14, 2015 (incorporated by reference to Exhibit 3.2 to Registrant’s Current Report on Form 8-K filed May 20, 2015, SEC File No. 001-4300).
3.3	–	Bylaws of Registrant, as amended May 11, 2017 (incorporated by reference to Exhibit 3.1 to Registrant’s Current Report on Form 8-K filed May 16, 2017, SEC File No. 001-4300).
10.1	–	Form of 2019 Performance Share Program (2016 Omnibus Compensation Plan), dated January 3, 2019 (incorporated by reference to Exhibit 10.1 to Registrant’s Current Report on Form 8-K filed January 7, 2019, SEC File No. 001-04300).
10.2	–	Form of 2019 Cash-Based Restricted Stock Unit Grant Agreement (2016 Omnibus Compensation Plan), dated January 3, 2019 (incorporated by reference to Exhibit 10.2 to Registrant’s Current Report on Form 8-K filed January 7, 2019, SEC File No. 001-04300).
*31.1	–	Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the Exchange Act) by Principal Executive Officer.
*31.2	–	Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the Exchange Act) by Principal Financial Officer.
*32.1	–	Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906) by Principal Executive Officer and Principal Financial Officer.
*101.SCH	–	XBRL Taxonomy Schema Document.
*101.CAL	–	XBRL Calculation Linkbase Document.
*101.DEF	–	XBRL Definition Linkbase Document.
*101.LAB	–	XBRL Label Linkbase Document.
*101.PRE	–	XBRL Presentation Linkbase Document.

* Filed herewith

34

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

		APACHE CORPORATION
Dated:	May 2, 2019	/s/ STEPHEN J. RINEY
		Stephen J. Riney
		Executive Vice President and Chief Financial Officer
		(Principal Financial Officer)
Dated:	May 2, 2019	/s/ REBECCA A. HOYT
		Rebecca A. Hoyt
		Senior Vice President, Chief Accounting Officer, and Controller
		(Principal Accounting Officer)

35

EX-31.1

EXHIBIT 31.1

CERTIFICATIONS

I, John J. Christmann IV, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Apache Corporation;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
	(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
	(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ John J. Christmann IV

John J. Christmann IV

Chief Executive Officer and President

(principal executive officer)

Date: May 2, 2019

EX-31.2

EXHIBIT 31.2

CERTIFICATIONS

I, Stephen J. Riney, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Apache Corporation;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
	(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
	(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ Stephen J. Riney

Stephen J. Riney

Executive Vice President and Chief Financial Officer

(principal financial officer)

Date: May 2, 2019

EX-32.1

EXHIBIT 32.1

APACHE CORPORATION

Certification of Principal Executive Officer

and Principal Financial Officer

I, John J. Christmann IV, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge, the quarterly report on Form 10-Q of Apache Corporation for the quarterly period ending March 31, 2019, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. §78m or §78o (d)) and that information contained in such report fairly represents, in all material respects, the financial condition and results of operations of Apache Corporation.

/s/ John J. Christmann IV
By:	John J. Christmann IV
Title:	Chief Executive Officer and President
	(principal executive officer)

Date: May 2, 2019

I, Stephen J. Riney, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge, the quarterly report on Form 10-Q of Apache Corporation for the quarterly period ending March 31, 2019, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. §78m or §78o (d)) and that information contained in such report fairly represents, in all material respects, the financial condition and results of operations of Apache Corporation.

/s/ Stephen J. Riney
By:	Stephen J. Riney
Title:	Executive Vice President and Chief Financial Officer
	(principal financial officer)

Date: May 2, 2019

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 30, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	APA
Entity Registrant Name	APACHE CORPORATION
Entity Central Index Key	0000006769
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		375,920,593

XML

STATEMENT OF CONSOLIDATED OPERATIONS (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
REVENUES AND OTHER:
Oil and gas production revenues	$ 1,654	$ 1,733
Derivative instrument gains (losses), net	(30)	2
Gain on divestitures	3	7
Other	8	5
Total revenues and other	1,635	1,747
OPERATING EXPENSES:
Lease operating expenses	365	349
Gathering, processing, and transmission	88	86
Taxes other than income	51	55
Exploration	69	76
General and administrative	123	114
Transaction, reorganization, and separation	4	0
Depreciation, depletion, and amortization	646	553
Asset retirement obligation accretion	27	27
Financing costs, net	97	99
Total operating expenses	1,470	1,359
NET INCOME BEFORE INCOME TAXES	165	388
Current income tax provision	186	198
Deferred income tax benefit	(19)	(16)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(2)	206
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$ (47)	$ 145
NET INCOME (LOSS) PER COMMON SHARE:
Basic (in USD per share)	$ (0.12)	$ 0.38
Diluted (in USD per share)	$ (0.12)	$ 0.38
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic (in shares)	376	382
Diluted (in shares)	376	384
DIVIDENDS DECLARED PER COMMON SHARE (in USD per share)	$ 0.25	$ 0.25
Oil
REVENUES AND OTHER:
Oil and gas production revenues	$ 1,310	$ 1,393
Natural Gas
REVENUES AND OTHER:
Oil and gas production revenues	236	222
Natural gas liquids
REVENUES AND OTHER:
Oil and gas production revenues	108	118
Noncontrolling interest, Egypt
OPERATING EXPENSES:
Net income attributable to noncontrolling interest	44	61
Noncontrolling interest, Altus
OPERATING EXPENSES:
Net income attributable to noncontrolling interest	$ 1	$ 0

XML

STATEMENT OF CONSOLIDATED CASH FLOWS (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) including noncontrolling interest	$ (2)	$ 206
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Unrealized derivative instrument (gains) losses, net	45	(49)
Gain on divestitures	(3)	(7)
Exploratory dry hole expense and unproved leasehold impairments	33	36
Depreciation, depletion, and amortization	646	553
Asset retirement obligation accretion	27	27
Deferred income tax benefit	(19)	(16)
Other	9	39
Changes in operating assets and liabilities:
Receivables	8	(65)
Inventories	(33)	(33)
Drilling advances	5	(41)
Deferred charges and other	(4)	32
Accounts payable	(50)	66
Accrued expenses	(46)	(139)
Deferred credits and noncurrent liabilities	(18)	6
NET CASH PROVIDED BY OPERATING ACTIVITIES	598	615
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(729)	(737)
Leasehold and property acquisitions	(15)	(12)
Additions to Altus gathering, processing, and transmission facilities	(119)	(128)
Equity method interests - Altus	(118)	0
Proceeds from sale of oil and gas properties	9	9
Other, net	34	(22)
NET CASH USED IN INVESTING ACTIVITIES	(938)	(890)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper	159	0
Payments on fixed-rate debt	0	(150)
Distributions to noncontrolling interest - Egypt	(107)	(69)
Dividends paid	(94)	(95)
Other	(5)	(2)
NET CASH USED IN FINANCING ACTIVITIES	(47)	(316)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(387)	(591)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	714	1,668
CASH AND CASH EQUIVALENTS AT END OF PERIOD	327	1,077
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest	115	140
Income taxes paid, net of refunds	$ 165	$ 191

XML

CONSOLIDATED BALANCE SHEET (Unaudited) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
CURRENT ASSETS:
Cash and cash equivalents ($177 and $450, respectively, related to Altus VIE)	$ 327	$ 714
Receivables, net of allowance	1,185	1,194
Inventories ($6 and $6, respectively, related to Altus VIE)	438	401
Drilling advances	213	218
Assets held for sale	217	0
Prepaid assets and other	124	160
Total current assets	2,504	2,687
Oil and gas, on the basis of successful efforts accounting:
Proved properties	42,462	42,345
Unproved properties and properties under development	1,371	1,435
Gathering, processing, and transmission facilities ($1,353 and $1,251, respectively, related to Altus VIE)	1,958	1,856
Other ($38 and nil, respectively, related to Altus VIE)	1,154	1,120
Property and equipment, gross	46,945	46,756
Less: Accumulated depreciation, depletion, and amortization ($32 and $24, respectively, related to Altus VIE)	(28,654)	(28,335)
Property and equipment, net	18,291	18,421
OTHER ASSETS:
Equity method interests ($209 and $91, respectively, related to Altus VIE)	209	121
Deferred charges and other	747	353
Total assets	21,751	21,582
CURRENT LIABILITIES:
Accounts payable	679	709
Current debt ($29 and nil, respectively, related to Altus VIE)	339	151
Other current liabilities (Note 6) ($72 and $85, respectively, related to Altus VIE)	1,356	1,341
Total current liabilities	2,374	2,201
LONG-TERM DEBT	8,094	8,093
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	370	391
Asset retirement obligation ($30 and $29, respectively, related to Altus VIE)	1,879	1,866
Other	425	219
Total deferred credits and other noncurrent liabilities	2,674	2,476
COMMITMENTS AND CONTINGENCIES (Note 10)
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 416,874,466 and 415,692,116 shares issued, respectively	261	260
Paid-in capital	12,009	12,106
Accumulated deficit	(2,095)	(2,048)
Treasury stock, at cost, 40,964,193 and 40,995,894 shares, respectively	(3,190)	(3,192)
Accumulated other comprehensive income	4	4
APACHE SHAREHOLDERS’ EQUITY	6,989	7,130
TOTAL EQUITY	8,609	8,812
TOTAL LIABILITIES AND EQUITY	21,751	21,582
Noncontrolling interest, Egypt
EQUITY:
Noncontrolling interest	1,212	1,275
Noncontrolling interest, Altus
EQUITY:
Noncontrolling interest	$ 408	$ 407

XML

CONSOLIDATED BALANCE SHEET (Unaudited) (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Cash and cash equivalents	$ 327	$ 714
Inventories	438	401
Gathering, transmission and processing facilities	1,958	1,856
Other	1,154	1,120
Less: Accumulated depreciation, depletion, and amortization	(28,654)	(28,335)
Equity method interests	209	121
Current debt	339	151
Other current liabilities	1,356	1,341
Asset retirement obligation	$ 1,879	$ 1,866
Common stock, par value (in USD per share)	$ 0.625	$ 0.625
Common stock, shares authorized (in shares)	860,000,000	860,000,000
Common stock, shares issued (in shares)	416,874,466	415,692,116
Treasury stock, shares (in shares)	40,964,193	40,995,894
Altus VIE
Cash and cash equivalents	$ 177	$ 450
Inventories	6	6
Gathering, transmission and processing facilities	1,353	1,251
Other	38	0
Less: Accumulated depreciation, depletion, and amortization	(32)	(24)
Equity method interests	209	91
Current debt	29	0
Other current liabilities	72	85
Asset retirement obligation	$ 30	$ 29

XML

STATEMENT OF CONSOLIDATED CHANGES IN EQUITY (Unaudited) - USD ($) $ in Millions	Total	Common Stock	Paid-In Capital	Accumulated Deficit	Treasury Stock	Accumulated Other Comprehensive Income	APACHE SHAREHOLDERS’ EQUITY	Noncontrolling Interest	Noncontrolling interest, Egypt	Noncontrolling interest, Altus
Beginning Balance at Dec. 31, 2017	$ 8,791	$ 259	$ 12,128	$ (2,088)	$ (2,887)	$ 4	$ 7,416	$ 1,375
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	206			145			145	61
Net loss attributable to common stock	145
Net income attributable to noncontrolling interest									$ 61	$ 0
Distributions to noncontrolling interest	(69)							(69)
Common dividends ($0.25 per share)	(96)		(96)				(96)
Other	37		37				37
Ending Balance at Mar. 31, 2018	8,869	259	12,069	(1,943)	(2,887)	4	7,502	1,367
Beginning Balance at Dec. 31, 2018	8,812	260	12,106	(2,048)	(3,192)	4	7,130	1,682
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	(2)
Net loss attributable to common stock	(47)			(47)			(47)
Net income attributable to noncontrolling interest									$ 44	$ 1
Distributions to noncontrolling interest	(107)							(107)
Common dividends ($0.25 per share)	(94)		(94)				(94)
Other	0	1	(3)		2
Ending Balance at Mar. 31, 2019	$ 8,609	$ 261	$ 12,009	$ (2,095)	$ (3,190)	$ 4	$ 6,989	$ 1,620

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STATEMENT OF CONSOLIDATED CHANGES IN EQUITY (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Stockholders' Equity [Abstract]
Common stock, dividends, per share (in USD per share)	$ 0.25	$ 0.25

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Mar. 31, 2019

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

As of March 31, 2019, 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, 2018, with the exception of Accounting Standards Update (ASU) 2016-02, “Leases (Topic 842)” (see “Leases” section in this Note 1 below).

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of Apache and its subsidiaries after elimination of intercompany balances and transactions. The Company’s undivided interests in oil and gas exploration and production ventures and partnerships are proportionately consolidated. The Company consolidates all other investments in which, either through direct or indirect ownership, Apache has more than a 50 percent voting interest or controls the financial and operating decisions. Noncontrolling interests represent third-party ownership in the net assets of a consolidated Apache subsidiary and are reflected separately in the Company’s financial statements. Sinopec International Petroleum Exploration and Production Corporation (Sinopec) owns a one-third minority participation in Apache’s Egypt oil and gas business as a noncontrolling interest, which is reflected as a separate component of equity in Apache’s consolidated balance sheet.

Additionally, third-party investors own a minority interest of approximately 21 percent of Altus Midstream Company (ALTM), which is reflected as a separate noncontrolling interest component of equity in Apache’s consolidated balance sheet. Apache consolidates the activities of ALTM, which qualifies as a variable interest entity (VIE) under GAAP. Apache has concluded that it is the primary beneficiary of the VIE, as defined in the accounting standards, since Apache has the power, through its ownership, to direct those activities that most significantly impact the economic performance of ALTM and the obligation to absorb losses or the right to receive benefits that could be potentially significant to ALTM. This conclusion was based on a qualitative analysis that considered ALTM’s governance structure, the commercial agreements between ALTM, Altus Midstream LP (collectively with ALTM, Altus), and Apache, and the voting rights established between the members, which provide Apache with the ability to control the operations of Altus.

Investments in which Apache holds less than 50 percent of the voting interest are typically accounted for under the equity method of accounting, with the balance recorded separately as “Equity method interests” in Apache’s consolidated balance sheet and results of operations recorded as a component of “Other” under “Revenues and Other” in the Company’s statement of consolidated operations.

Use of Estimates

Preparation of financial statements in conformity with GAAP 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 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).

Recurring fair value measurements are presented in further detail in Note 4—Derivative Instruments and Hedging Activities and Note 9—Debt and Financing Costs.

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 each of the first quarters of 2019 and 2018.

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 associated proved oil and gas properties. 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 well 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 the carrying value of proved oil and gas properties may not be recoverable, 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 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 first quarters of 2019 and 2018:

	Quarter Ended March 31,
	2019		2018
	(In millions)
Oil and Gas Property:
Proved	$	—	$	—
Unproved	23		16

On the statement of consolidated operations, unproved leasehold impairments are recorded as a component of “Exploration” expense, and all other impairments of proved and unproved properties are recorded separately in “Impairments,” when applicable.

Gains and losses on significant divestitures of the Company’s oil and gas properties are recognized in the statement of consolidated operations. See Note 2—Acquisitions and Divestitures for more detail.

Revenue Recognition

Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, million Btu (MMBtu) of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Company considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Company’s right to payment, and transfer of legal title. In each case, the term between delivery and when payments are due is not significant.

Apache markets its own United States (U.S.) natural gas and crude oil production based on market-priced contracts. Typically, these contracts are adjusted for quality, transportation, and other market-reflective differentials. Since the Company’s production fluctuates because of operational issues, it is occasionally necessary to purchase third-party oil and gas to fulfill sales obligations and commitments. Sales proceeds related to third-party oil and gas purchases have been determined to be revenue from a customer. Proceeds for these volumes totaled $24 million and $104 million, for the periods ending March 31, 2019 and 2018, respectively. Associated purchase costs for these volumes totaled $22 million and $105 million, for the periods ending March 31, 2019 and 2018, respectively. Proceeds and costs are both recorded as “Other” under “Revenues and Other” in the statement of consolidated operations.

Internationally, Apache’s crude oil offshore the U.K. in the North Sea (North Sea) is sold under contracts with a market-based index price. Natural gas from the North Sea Beryl field is processed through the SAGE gas plant. The gas is sold to a third party at the St. Fergus entry point of the national grid on a National Balancing Point index price basis. Apache’s gas production in Egypt is sold primarily under an industry-pricing formula, a sliding scale based on Dated Brent crude oil with a minimum of

$1.50 per MMBtu and a maximum of $2.65 per MMBtu, plus an upward adjustment for liquids content. The Company’s Egypt oil production is sold at prices equivalent to the export market.

The Company’s Egyptian operations are conducted pursuant to production sharing contracts under which contractor partners pay all operating and capital costs for exploring and developing the concessions. A percentage of the production, generally up to 40 percent, is available to contractor partners to recover these operating and capital costs over contractually defined periods. The balance of the production is split among the contractor partners and the Egyptian General Petroleum Corporation (EGPC) on a contractually defined basis. Additionally, the contractor partner’s income taxes, which remain the liability of the contractor partners under domestic law, are paid by EGPC on behalf of the contractor partners out of EGPC’s production entitlement. Income taxes paid to the Arab Republic of Egypt on behalf of Apache as contract partner are recognized as oil and gas sales revenue and income tax expense and reflected as production and estimated reserves. Revenues related to Egypt’s tax volumes are considered revenue from a non-customer.

For the period ending March 31, 2019, revenues from customers and non-customers were $1.6 billion and $119 million, respectively. For the period ending March 31, 2018, revenues from customers and non-customers were $1.7 billion and $155 million, respectively.

Apache records trade accounts receivable for its unconditional rights to consideration arising under sales contracts with customers. The carrying value of such receivables, net of the allowance for doubtful accounts, represents estimated net realizable value. The Company routinely assesses the collectability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Receivables from contracts with customers, net of allowance for doubtful accounts, totaled $1.0 billion as of March 31, 2019 and December 31, 2018.

Apache has concluded that disaggregating revenue by geographic area and by product appropriately depicts how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. Refer to Note 12—Business Segment Information for a disaggregation of revenue by each product sold.

Leases

On January 1, 2019, Apache adopted ASU 2016-02, “Leases (Topic 842),” which requires lessees to recognize separate right-of-use (ROU) assets and lease liabilities for most leases classified as operating leases under previous GAAP. Prior to adoption, the Financial Accounting Standards Board (FASB) issued transition guidance permitting an entity the option to not evaluate under ASU 2016-02 those existing or expired land easements that were not previously accounted for as leases, as well as an option to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the financial statements. Apache elected both transitional practical expedients. Under these transition options, comparative reporting was not required, and the provisions of the standard were applied prospectively to leases in effect at the date of adoption.

As allowed under the standard, the Company also applied practical expedients to carry forward its historical assessments of whether existing agreements contain a lease, classification of existing lease agreements, and treatment of initial direct lease costs. Apache also elected to exclude short-term leases (those with terms of 12 months or less) from the balance sheet presentation and accounts for non-lease and lease components as a single lease component for all asset classes. Short-term lease expense was not material for the first quarter of 2019.

The Company determines if an arrangement is an operating or finance lease at the inception of each contract. If the contract is classified as an operating lease, Apache records an ROU asset and corresponding liability reflecting the total remaining present value of fixed lease payments over the expected term of the lease agreement. The expected term of the lease may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. If the Company’s lease does not provide an implicit rate in the contract, the Company uses its incremental borrowing rate when calculating the present value. In the normal course of business, Apache enters into various lease agreements for real estate, drilling rigs, vessels, aircraft, and equipment related to its exploration and development activities, which are typically classified as operating leases under the provisions of the standard. ROU assets are reflected within “Deferred charges and other assets” on the Company’s consolidated balance sheet, and the associated operating lease liabilities are reflected within “Other current liabilities” and “Other noncurrent liabilities,” as applicable.

Operating lease expense associated with ROU assets is recognized on a straight-line basis over the lease term. Lease expense is reflected on the statement of consolidated operations commensurate with the leased activities and nature of the services performed. Fixed operating lease expense was $55 million for the first quarter of 2019.

In addition, the Company periodically enters into finance leases that are similar to those leases classified as capital leases under previous GAAP. Finance lease assets are included in property, plant, and equipment on the consolidated balance sheet, and the associated finance lease liabilities are reflected within “Current debt” and “Long-term debt,” as applicable. Prior periods include the reclassification of $39 million finance lease obligations from “Other noncurrent liabilities” to “Long-term debt” to conform with this presentation. There was no material impact to the Company’s statement of consolidated operations and statement of consolidated cash flows for its treatment of finance leases.

The following table represents the Company’s weighted average lease term and discount rate as of March 31, 2019:

	Operating Leases		Finance Leases
Weighted average remaining lease term	3.4 years		8.7 years
Weighted average discount rate	4.3	%	4.3	%

The undiscounted future minimum lease payments reconciled to the carrying value of the lease liabilities as of March 31, 2019 were as follows:

Net Minimum Commitments	Operating Leases(1)			Finance Leases(2)
	(In millions)
2019	$	159		$	22
2020	111			13
2021	46			3
2022	40			3
2023	24			3
Thereafter	41			39
Total future minimum lease payments	421			83
Less: imputed interest	(34		)	(15		)
Total lease liabilities	387			68
Current portion	(187		)	(30		)
Non-current portion	$	200		$	38

(1) Amounts included for drilling rig and related operational equipment obligations represent future payments associated with oil and gas operations gross of amounts billable to partners and other working interest owners. Such payments may be capitalized as a component of oil and gas properties, and either depreciated, impaired, or written off as exploration expense.

(2) Amounts represent the Company’s finance lease obligation related to physical power generators being leased on a one-year term with the right to purchase (entered into during the first quarter of 2019) and a separate lease for the Company’s Midland, Texas regional office building.

The lease liability reflected in the table above represents the Company’s fixed minimum payments that are settled in accordance with the lease terms. Actual lease payments during the period may also include variable lease components such as common area maintenance, usage-based sales taxes and rate differentials, or other similar costs that are not determinable at the inception of the lease. Variable lease payments for the period ended March 31, 2019 were $17 million.

New Pronouncements Issued But Not Yet Adopted

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments-Credit Losses.” The standard changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, held-to-maturity debt securities and loans, and requires entities to use a new forward-looking expected loss model that will result in the earlier recognition of allowance for losses. This update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Entities will apply the standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The Company is evaluating the new guidance and does not believe this standard will have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-13, “Disclosure Framework: Changes to the Disclosure Requirements for Fair Value Measurement,” which changes the disclosure requirements for fair value measurements by removing, adding, and modifying certain disclosures. ASU 2018-13 is effective for financial statements issued for annual periods beginning after December 15, 2019, and interim periods within those annual periods. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-14, “Disclosure Framework: Changes to the Disclosure Requirements for Defined Benefit Plans,” which eliminates, modifies, and adds disclosure requirements for defined benefit plans. The ASU is effective for financial statements issued for fiscal years ending after December 15, 2020. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-15, “Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract.” This pronouncement clarifies the requirements for capitalizing implementation costs in cloud computing arrangements and aligns them with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. This pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted, including adoption in any interim period for which financial statements have not been issued. The Company is currently evaluating the impact of adoption of this ASU on its consolidated financial statements and does not expect it to have a material impact.

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ACQUISITIONS AND DIVESTITURES

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

ACQUISITIONS AND DIVESTITURES

ACQUISITIONS AND DIVESTITURES

2019 Activity

During the first quarter of 2019, Apache completed leasehold and property acquisitions for total cash consideration of $15 million primarily in its U.S. onshore regions. During the first quarter, the Company also completed the sale of certain non-core assets, primarily in the Permian region, in multiple transactions for total cash proceeds of $9 million. The Company recognized a total gain of approximately $3 million upon closing of these transactions.

In March 2019, Apache entered into an agreement to sell certain non-core assets in Oklahoma for $245 million, subject to normal and customary closing adjustments. As a result of the agreement, the associated assets and liabilities qualified as held for sale as of March 31, 2019. Property, plant, and equipment totaling $217 million were classified as current assets held for sale, and an asset retirement obligation of $6 million was classified as a current liability held for sale. The transaction is expected to close in the second quarter of 2019.

Subsequent to March 31, 2019, Apache entered into an agreement to sell certain non-core assets in south Texas for $43 million, subject to normal and customary closing adjustments. The transaction is expected to close in the second quarter of 2019. No material gain or loss is expected on the sale.

2018 Activity

During the first quarter of 2018, Apache completed $12 million of leasehold and property acquisitions primarily in its U.S. onshore regions. During the first quarter, the Company also completed the sale of certain non-core assets, primarily in the Permian region, in multiple transactions for total cash proceeds of $9 million. The Company recognized a total gain of approximately $7 million during the first quarter upon closing of these transactions.

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CAPITALIZED EXPLORATORY WELL COSTS	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
CAPITALIZED EXPLORATORY WELL COSTS	CAPITALIZED EXPLORATORY WELL COSTSThe Company’s capitalized exploratory well costs were $123 million and $159 million at March 31, 2019 and December 31, 2018, respectively. The decrease is primarily attributable to successful transfers of well costs, partially offset by additional drilling activities during the period. No suspended exploratory well costs previously capitalized for greater than one year at December 31, 2018 were charged to dry hole expense during the three months ended March 31, 2019. 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 proved reserves can be attributed to these projects.

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

3 Months Ended

Mar. 31, 2019

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, currency exchange rates, and interest rates. The Company utilizes various types of derivative financial instruments to manage fluctuations in cash flows resulting from these fluctuations. Apache has elected not to designate any of its derivative contracts as cash flow hedges.

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 March 31, 2019, 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

Commodity Derivative Instruments

As of March 31, 2019, Apache had the following open crude oil financial basis swap contracts:

Production Period	Settlement Index	Mbbls	Weighted Average Price Differential
April—September 2019	Midland-WTI/Cushing-WTI	4,941	$(8.60)
October—December 2019	Midland-WTI/Cushing-WTI	1,380	$(3.72)

As of March 31, 2019, Apache had the following open natural gas costless collar contracts:

Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Floor Price	Weighted Average Ceiling Price
April—June 2019	NYMEX Henry Hub	9,100	$3.00	$3.92

As of March 31, 2019, Apache had the following open natural gas financial basis swap contracts:

		Basis Swap Purchased		Basis Swap Sold
Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Price Differential	MMBtu (in 000’s)	Weighted Average Price Differential
April—June 2019	NYMEX Henry Hub/Waha	10,920	$(1.74)	16,380	$(0.53)
April—June 2019	NYMEX Henry Hub/EP Permian	—	—	10,920	$(1.58)
April—December 2019	NYMEX Henry Hub/Waha	—	—	11,000	$(0.45)

Foreign Currency Derivative Instruments

Apache has open foreign currency costless collar contracts in GBP/USD for £12.5 million per each calendar month for 2019 with a weighted average floor and ceiling price of $1.20 and $1.35, respectively.

Interest Rate Derivative Instruments

Apache has open U.S. treasury lock contracts with an aggregate notional amount of $400 million.

Fair Value Measurements

The fair values of the Company’s derivative contracts 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 futures pricing for the underlying positions 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)
March 31, 2019
Assets:
Commodity Derivative Instruments	$	—	$	50	$	—	$	50	$	(14	)	$	36
Foreign Currency Derivative Instruments	—		1		—		1		—			1
Liabilities:
Commodity Derivative Instruments	—		46		—		46		(14		)	32
Interest Rate Derivative Instruments	—		6		—		6		—			6
December 31, 2018
Assets:
Commodity Derivative Instruments	$	—	$	69	$	—	$	69	$	(14	)	$	55
Liabilities:
Commodity Derivative Instruments	—		25		—		25		(14		)	11

(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:

	March 31, 2019		December 31, 2018
	(In millions)
Current Assets: Prepaid assets and other	$	37	$	55
Total Assets	$	37	$	55
Current Liabilities: Other current liabilities	$	38	$	11
Total Liabilities	$	38	$	11

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 March 31,
	2019			2018
	(In millions)
Realized gain (loss):
Derivative settlements, realized gain (loss)	$	15		$	(42	)
Amortization of put premium, realized loss	—			(5		)
Unrealized gain (loss)	(45		)	49
Derivative instrument gains (losses), net	$	(30	)	$	2

Derivative instrument gains and losses are recorded in “Derivative instrument gains (losses), net” under “Revenues and Other” in the Company’s statement of consolidated operations. Unrealized gains and losses for derivative activity recorded in the statement of consolidated operations are reflected in the statement of consolidated cash flows separately as “Unrealized derivative instrument gains (losses), net” in “Adjustments to reconcile net income (loss) to net cash provided by operating activities.”

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EQUITY METHOD INTERESTS

3 Months Ended

Mar. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

EQUITY METHOD INTERESTS

EQUITY METHOD INTERESTS

Apache, through its ownership of Altus, consolidates the following equity method interests in Permian Basin pipelines. For each of the equity method interests, Altus has the ability to exercise significant influence based on certain governance provisions and its participation in the significant activities and decisions that impact the management and economic performance of the equity method interests.

	March 31, 2019				December 31, 2018
	Interest		Amount		Interest		Amount
	($ in millions)
Gulf Coast Express Pipeline LLC	15.0	%	$	157	15.0	%	$	91
EPIC Crude Holdings, LP	15.0	%	52		—		—
			$	209			$	91

The equity method interest balance as of March 31, 2019 and December 31, 2018 were $1 million and $6 million, respectively, less than Apache’s underlying equity in the separate net assets within the financial statements of the respective entities. Unamortized differences will be amortized into net income over the remaining useful lives of the associated pipelines, when they are placed into service.

The following table presents the activity in Apache’s equity method interests for the three months ended March 31, 2019:

	Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Total
	(In millions)
Balance at December 31, 2018	$	91	$	—	$	91
Acquisitions	—		52		52
Contributions	66		—		66
Balance at March 31, 2019	$	157	$	52	$	209

As of December 31, 2018, Apache also held an investment in Marine Well Containment Company. This investment was sold in the first quarter of 2019 for $30 million, with no gain or loss recorded on the sale.

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OTHER CURRENT LIABILITIES

3 Months Ended

Mar. 31, 2019

Payables and Accruals [Abstract]

OTHER CURRENT LIABILITIES

OTHER CURRENT LIABILITIES

The following table provides detail of the Company’s other current liabilities as of March 31, 2019 and December 31, 2018:

	March 31, 2019		December 31, 2018
	(In millions)
Accrued operating expenses	$	72	$	65
Accrued exploration and development	552		667
Accrued gathering, processing, and transmission - Altus	63		81
Accrued compensation and benefits	96		177
Accrued interest	121		137
Accrued income taxes	60		58
Current asset retirement obligation	66		66
Current operating lease liability	187		—
Other	139		90
Total other current liabilities	$	1,356	$	1,341

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ASSET RETIREMENT OBLIGATION

3 Months Ended

Mar. 31, 2019

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 three-month period ended March 31, 2019:

	(In millions)
Asset retirement obligation at December 31, 2018	$	1,932
Liabilities incurred	3
Liabilities settled	(11		)
Liabilities held for sale	(6		)
Accretion expense	27
Asset retirement obligation at March 31, 2019	1,945
Less current portion	(66		)
Asset retirement obligation, long-term	$	1,879

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INCOME TAXES

3 Months Ended

Mar. 31, 2019

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

The Company estimates its annual effective income tax rate 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.

During the first quarter of 2019, Apache’s effective income tax rate was primarily impacted by an increase in the amount of valuation allowance against its U.S. deferred tax assets. During the first quarter of 2018, Apache’s effective income tax rate was also primarily impacted by an increase in the amount of valuation allowance against its U.S. 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. The Company is currently under IRS audit for the 2014-2016 tax years and is also under audit in various states and foreign jurisdictions as part of its normal course of business.

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DEBT AND FINANCING COSTS

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

DEBT AND FINANCING COSTS

DEBT AND FINANCING COSTS

The following table presents the carrying value of the Company’s debt as of March 31, 2019 and December 31, 2018:

	March 31, 2019			December 31, 2018
	(In millions)
Notes and debentures before unamortized discount and debt issuance costs	$	8,299		$	8,299
Commercial paper	159			—
Finance lease obligations	68			40
Unamortized discount	(43		)	(44		)
Debt issuance costs	(50		)	(51		)
Total debt	8,433			8,244
Current maturities	(339		)	(151		)
Long-term debt	$	8,094		$	8,093

As of March 31, 2019, current debt included $150 million of 7.625% senior notes due July 1, 2019, $159 million of commercial paper, and $30 million of finance lease obligations. As of December 31, 2018, current debt included $150 million of 7.625% senior notes due July 1, 2019 and $1 million of finance lease obligations.

The fair value of the Company’s notes and debentures was $8.3 billion and $7.8 billion as of March 31, 2019 and December 31, 2018, respectively. 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).

In March 2018, the Company entered into a revolving credit facility with commitments totaling $4.0 billion. In March 2019, the term of this facility was extended by one year to March 2024 (subject to Apache’s remaining one-year extension option) pursuant to Apache’s exercise of an extension option. The Company can increase commitments up to $5.0 billion by adding new lenders or obtaining the consent of any increasing existing lenders. The facility includes a letter of credit subfacility of up to $3.0 billion, of which $2.08 billion was committed as of March 31, 2019. The facility is for general corporate purposes, and committed borrowing capacity fully supports Apache’s commercial paper program. As of March 31, 2019, letters of credit aggregating approximately £3.1 million and no borrowings were outstanding under this facility.

The Company’s $3.5 billion commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of March 31, 2019, the Company had $159 million of commercial paper outstanding.

In November 2018, Altus Midstream LP, an indirectly controlled subsidiary of Apache, entered into a revolving credit facility for general corporate purposes that matures in November 2023 (subject to Altus Midstream LP’s two, one-year extension options). The agreement for this facility provides aggregate commitments from a syndicate of banks of $450 million until (i) the consolidated net income of Altus Midstream LP and its restricted subsidiaries, as adjusted pursuant to the agreement, for three consecutive calendar months equals or exceeds $175 million on an annualized basis and (ii) Altus Midstream LP has raised at least $250 million of additional capital (such period, the Initial Period). Following the Initial Period, the aggregate commitments equal $800 million. All aggregate commitments include a letter of credit subfacility of up to $100 million and a swingline loan subfacility of up to $100 million. After the Initial Period, Altus Midstream LP may increase commitments up to an aggregate $1.5 billion by adding new lenders or obtaining the consent of any increasing existing lenders. As of March 31, 2019, no borrowings or letters of credit were outstanding under this facility. The Altus Midstream LP credit facility is unsecured and is not guaranteed by Apache or any of Apache’s other subsidiaries.

Financing Costs, Net

The following table presents the components of Apache’s financing costs, net:

	For the Quarter Ended March 31,
	2019			2018
	(In millions)
Interest expense	$	107		$	112
Amortization of deferred loan costs	2			5
Capitalized interest	(8		)	(12		)
Interest income	(4		)	(6		)
Financing costs, net	$	97		$	99

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COMMITMENTS AND CONTINGENCIES

3 Months Ended

Mar. 31, 2019

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 March 31, 2019, the Company has an accrued liability of approximately $35 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 9—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, 2018.

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, 2018.

Louisiana Restoration 

As more fully described in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, Louisiana surface owners often file lawsuits or assert claims against oil and gas companies, including Apache, claiming that operators and working interest owners in the chain of title are liable for environmental damages on the leased premises, including damages measured by the cost of restoration of the leased premises to its original condition, regardless of the value of the underlying property. From time to time restoration lawsuits and claims are resolved by the Company for amounts that are not material to the Company, while new lawsuits and claims are asserted against the Company. With respect to each of the pending lawsuits and claims, the amount claimed is not currently determinable or is not material, except as noted. Further, the overall exposure related to these lawsuits and claims is not currently determinable. While an adverse judgment against Apache is possible, Apache intends to actively defend these lawsuits and claims.

Starting in November of 2013 and continuing into 2019, several parishes in Louisiana have pending lawsuits against many oil and gas producers, including Apache. These cases have all been removed to federal 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 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, 2018.

Apollo Exploration Lawsuit

In a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation, Cause No. CV50538 in the 385th Judicial District Court, Midland County, Texas, plaintiffs alleged damages in excess of $200 million (having previously claimed in excess of $1.1 billion) relating to 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 motions filed by Apache reducing the plaintiffs’ alleged damages to an amount that is not material to the Company. Apache believes that plaintiffs’ claims lack merit and 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, 2018.

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 Quadrant Energy Pty Ltd (Quadrant). Closing occurred on June 5, 2015. In April 2017, Apache filed suit against Quadrant for breach of the SPA. In its suit, Apache seeks approximately $80 million. In December 2017, Quadrant filed a defense of equitable set-off to Apache’s claim and a counterclaim seeking approximately $200 million in the aggregate. The Company believes that Quadrant’s claims lack merit and will not have a material adverse effect on the Company’s financial position, results of operation, or liquidity.

California Litigation

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. On December 20, 2017, in two separate actions, the City of Santa Cruz and Santa Cruz County and in a separate action on January 22, 2018, the City of Richmond, filed similar lawsuits against many of the same defendants. On November 14, 2018, the Pacific Coast Federation of Fishermen’s Associations, Inc. also filed a similar lawsuit against many of the same defendants. Apache believes that the claims made against it are baseless and intends to vigorously defend these lawsuits.

Castex Lawsuit

In a case styled Apache Corporation v. Castex Offshore, Inc, et. al., Cause No. 2015-48580, in the 113rd Judicial District Court of Harris County, Texas, Castex filed claims for alleged damages which they recently disclosed to be approximately $200 million, relating to overspend on the Belle Isle Gas Facility upgrade, and the drilling of five sidetracks on the Potomac #3 Well. After a jury trial, a verdict of approximately $60 million was entered against Apache. Apache intends to appeal.

Environmental Matters

As of March 31, 2019, the Company had an undiscounted reserve for environmental remediation of approximately $5 million. The Company is not aware of any environmental claims existing as of March 31, 2019, 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.

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CAPITAL STOCK

3 Months Ended

Mar. 31, 2019

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 ended March 31, 2019 and 2018, is presented in the table below.

 

	For the Quarter Ended March 31,
	2019							2018
	Loss			Shares	Per Share			Income		Shares	Per Share
	(In millions, except per share amounts)
Basic:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	382	$	0.38
Effect of Dilutive Securities:
Stock options and other	$	—		—	$	—		$	—	2	$	—
Diluted:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	384	$	0.38

The diluted earnings per share calculation excludes options and restricted stock units that were anti-dilutive totaling 5.5 million and 6.7 million for the quarters ended March 31, 2019 and 2018, respectively.

Common Stock Dividends

For the quarters ended March 31, 2019, and 2018, Apache paid $94 million and $95 million, respectively, in dividends on its common stock.

Stock Repurchase Program

In 2013 and 2014, Apache’s Board of Directors authorized the purchase of up to 40 million shares of the Company’s common stock. Shares may be purchased from time to time either in the open market or through privately negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through March 31, 2019, had repurchased a total of 40 million shares at an average price of $79.18 per share. During the fourth quarter of 2018, the Company’s Board of Directors authorized the purchase of up to 40 million additional shares of the Company’s common stock. The Company is not obligated to acquire any specific number of shares and has not purchased any shares during 2019.

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BUSINESS SEGMENT INFORMATION

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

BUSINESS SEGMENT INFORMATION

BUSINESS SEGMENT INFORMATION

As of March 31, 2019, Apache is engaged in exploration and production (Upstream) activities across three operating segments: Egypt, the North Sea, and the U.S. Apache also has exploration interests in Suriname that may, over time, result in a reportable discovery and development opportunity. Apache’s Upstream business explores for, develops, and produces natural gas, crude oil and natural gas liquids. During the fourth quarter of 2018, Apache established a new reporting segment for its U.S. midstream business separate from its upstream oil and gas development activities. The midstream business is operated by Altus, which owns, develops, and operates a midstream energy asset network in the Permian Basin of West Texas, anchored by midstream service contracts to Apache’s production from its Alpine High resource play. Altus primarily generates revenue by providing fee-based natural gas gathering, compression, processing, and transportation services. Financial information for each segment is presented below:

	Egypt(1)		North Sea		U.S.		Altus		Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2019
Oil revenues	$	514	$	300	$	496	$	—	$	—		$	1,310
Natural gas revenues	81		32		123		—		—			236
Natural gas liquids revenues	4		6		98		—		—			108
Oil and gas production revenues	599		338		717		—		—			1,654
Midstream service affiliate revenues	—		—		—		34		(34		)	—
Operating Expenses:
Lease operating expenses	118		72		176		—		(1		)	365
Gathering, processing, and transmission	12		12		81		16		(33		)	88
Taxes other than income	—		—		48		3		—			51
Exploration	32		1		33		—		3			69
Depreciation, depletion, and amortization	188		99		352		7		—			646
Asset retirement obligation accretion	—		19		8		—		—			27
	350		203		698		26		(31		)	1,246
Operating Income (Loss)(3)	$	249	$	135	$	19	$	8	$	(3	)	408
Other Income (Expense):
Gain on divestitures												3
Derivative instrument losses, net												(30		)
Other(4)												8
General and administrative												(123		)
Transaction, reorganization, and separation												(4		)
Financing costs, net												(97		)
Income Before Income Taxes												$	165
Total Assets(5)	$	4,065	$	2,601	$	13,205	$	1,825	$	55		$	21,751

	Egypt(1)		North Sea		U.S.		Altus			Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2018
Oil revenues	$	569	$	271	$	553	$	—		$	—		$	1,393
Natural gas revenues	88		24		110		—			—			222
Natural gas liquids revenues	3		4		111		—			—			118
Oil and gas production revenues	660		299		774		—			—			1,733
Midstream service affiliate revenues	—		—		—		12			(12		)	—
Operating Expenses:
Lease operating expenses	98		93		158		—			—			349
Gathering, processing, and transmission	12		10		65		11			(12		)	86
Taxes other than income	—		—		52		3			—			55
Exploration	28		14		33		—			1			76
Depreciation, depletion, and amortization	186		95		269		3			—			553
Asset retirement obligation accretion	—		19		8		—			—			27
	324		231		585		17			(11		)	1,146
Operating Income (Loss)(3)	$	336	$	68	$	189	$	(5	)	$	(1	)	587
Other Income (Expense):
Gain on divestitures													7
Derivative instrument gains, net													2
Other(4)													5
General and administrative													(114		)
Financing costs, net													(99		)
Income Before Income Taxes													$	388
Total Assets(5)	$	4,813	$	3,009	$	13,106	$	821		$	42		$	21,791

(1) Includes revenue from non-customers of $107 million, $11 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2019, and $139 million, $15 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2018.

(2) Includes a noncontrolling interest in Egypt for the 2019 and 2018 periods, and Altus for the 2019 period.

(3) The operating income of U.S. and North Sea includes leasehold and unproved impairments totaling $21 million and $2 million, respectively, for the first quarter of 2019. The operating income of U.S. includes leasehold and unproved impairments totaling $16 million for the first quarter of 2018.

(4) Included in Other are sales proceeds related to U.S. third-party purchased oil and gas totaling $24 million and $104 million for the periods ending March 31, 2019 and 2018, respectively, which are determined to be revenue from customers.

(5)

Intercompany balances are excluded from total assets.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Mar. 31, 2019

Accounting Policies [Abstract]

Principles of Consolidation

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of Apache and its subsidiaries after elimination of intercompany balances and transactions. The Company’s undivided interests in oil and gas exploration and production ventures and partnerships are proportionately consolidated. The Company consolidates all other investments in which, either through direct or indirect ownership, Apache has more than a 50 percent voting interest or controls the financial and operating decisions. Noncontrolling interests represent third-party ownership in the net assets of a consolidated Apache subsidiary and are reflected separately in the Company’s financial statements. Sinopec International Petroleum Exploration and Production Corporation (Sinopec) owns a one-third minority participation in Apache’s Egypt oil and gas business as a noncontrolling interest, which is reflected as a separate component of equity in Apache’s consolidated balance sheet.

Additionally, third-party investors own a minority interest of approximately 21 percent of Altus Midstream Company (ALTM), which is reflected as a separate noncontrolling interest component of equity in Apache’s consolidated balance sheet. Apache consolidates the activities of ALTM, which qualifies as a variable interest entity (VIE) under GAAP. Apache has concluded that it is the primary beneficiary of the VIE, as defined in the accounting standards, since Apache has the power, through its ownership, to direct those activities that most significantly impact the economic performance of ALTM and the obligation to absorb losses or the right to receive benefits that could be potentially significant to ALTM. This conclusion was based on a qualitative analysis that considered ALTM’s governance structure, the commercial agreements between ALTM, Altus Midstream LP (collectively with ALTM, Altus), and Apache, and the voting rights established between the members, which provide Apache with the ability to control the operations of Altus.

Investments in which Apache holds less than 50 percent of the voting interest are typically accounted for under the equity method of accounting, with the balance recorded separately as “Equity method interests” in Apache’s consolidated balance sheet and results of operations recorded as a component of “Other” under “Revenues and Other” in the Company’s statement of consolidated operations.

Use of Estimates

Use of EstimatesPreparation of financial statements in conformity with 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 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).

Recurring fair value measurements are presented in further detail in Note 4—Derivative Instruments and Hedging Activities and Note 9—Debt and Financing Costs.

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 each of the first quarters of 2019 and 2018.

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 associated proved oil and gas properties. 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 well 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 the carrying value of proved oil and gas properties may not be recoverable, 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 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 first quarters of 2019 and 2018:

	Quarter Ended March 31,
	2019		2018
	(In millions)
Oil and Gas Property:
Proved	$	—	$	—
Unproved	23		16

On the statement of consolidated operations, unproved leasehold impairments are recorded as a component of “Exploration” expense, and all other impairments of proved and unproved properties are recorded separately in “Impairments,” when applicable.

Gains and losses on significant divestitures of the Company’s oil and gas properties are recognized in the statement of consolidated operations.

Revenue Recognition

Revenue Recognition

Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, million Btu (MMBtu) of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Company considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Company’s right to payment, and transfer of legal title. In each case, the term between delivery and when payments are due is not significant.

Apache markets its own United States (U.S.) natural gas and crude oil production based on market-priced contracts. Typically, these contracts are adjusted for quality, transportation, and other market-reflective differentials. Since the Company’s production fluctuates because of operational issues, it is occasionally necessary to purchase third-party oil and gas to fulfill sales obligations and commitments. Sales proceeds related to third-party oil and gas purchases have been determined to be revenue from a customer. Proceeds for these volumes totaled $24 million and $104 million, for the periods ending March 31, 2019 and 2018, respectively. Associated purchase costs for these volumes totaled $22 million and $105 million, for the periods ending March 31, 2019 and 2018, respectively. Proceeds and costs are both recorded as “Other” under “Revenues and Other” in the statement of consolidated operations.

Internationally, Apache’s crude oil offshore the U.K. in the North Sea (North Sea) is sold under contracts with a market-based index price. Natural gas from the North Sea Beryl field is processed through the SAGE gas plant. The gas is sold to a third party at the St. Fergus entry point of the national grid on a National Balancing Point index price basis. Apache’s gas production in Egypt is sold primarily under an industry-pricing formula, a sliding scale based on Dated Brent crude oil with a minimum of

$1.50 per MMBtu and a maximum of $2.65 per MMBtu, plus an upward adjustment for liquids content. The Company’s Egypt oil production is sold at prices equivalent to the export market.

The Company’s Egyptian operations are conducted pursuant to production sharing contracts under which contractor partners pay all operating and capital costs for exploring and developing the concessions. A percentage of the production, generally up to 40 percent, is available to contractor partners to recover these operating and capital costs over contractually defined periods. The balance of the production is split among the contractor partners and the Egyptian General Petroleum Corporation (EGPC) on a contractually defined basis. Additionally, the contractor partner’s income taxes, which remain the liability of the contractor partners under domestic law, are paid by EGPC on behalf of the contractor partners out of EGPC’s production entitlement. Income taxes paid to the Arab Republic of Egypt on behalf of Apache as contract partner are recognized as oil and gas sales revenue and income tax expense and reflected as production and estimated reserves. Revenues related to Egypt’s tax volumes are considered revenue from a non-customer.

For the period ending March 31, 2019, revenues from customers and non-customers were $1.6 billion and $119 million, respectively. For the period ending March 31, 2018, revenues from customers and non-customers were $1.7 billion and $155 million, respectively.

Apache records trade accounts receivable for its unconditional rights to consideration arising under sales contracts with customers. The carrying value of such receivables, net of the allowance for doubtful accounts, represents estimated net realizable value. The Company routinely assesses the collectability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Receivables from contracts with customers, net of allowance for doubtful accounts, totaled $1.0 billion as of March 31, 2019 and December 31, 2018.

Apache has concluded that disaggregating revenue by geographic area and by product appropriately depicts how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. Refer to Note 12—Business Segment Information for a disaggregation of revenue by each product sold.

Leases

Leases

On January 1, 2019, Apache adopted ASU 2016-02, “Leases (Topic 842),” which requires lessees to recognize separate right-of-use (ROU) assets and lease liabilities for most leases classified as operating leases under previous GAAP. Prior to adoption, the Financial Accounting Standards Board (FASB) issued transition guidance permitting an entity the option to not evaluate under ASU 2016-02 those existing or expired land easements that were not previously accounted for as leases, as well as an option to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the financial statements. Apache elected both transitional practical expedients. Under these transition options, comparative reporting was not required, and the provisions of the standard were applied prospectively to leases in effect at the date of adoption.

As allowed under the standard, the Company also applied practical expedients to carry forward its historical assessments of whether existing agreements contain a lease, classification of existing lease agreements, and treatment of initial direct lease costs. Apache also elected to exclude short-term leases (those with terms of 12 months or less) from the balance sheet presentation and accounts for non-lease and lease components as a single lease component for all asset classes. Short-term lease expense was not material for the first quarter of 2019.

The Company determines if an arrangement is an operating or finance lease at the inception of each contract. If the contract is classified as an operating lease, Apache records an ROU asset and corresponding liability reflecting the total remaining present value of fixed lease payments over the expected term of the lease agreement. The expected term of the lease may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. If the Company’s lease does not provide an implicit rate in the contract, the Company uses its incremental borrowing rate when calculating the present value. In the normal course of business, Apache enters into various lease agreements for real estate, drilling rigs, vessels, aircraft, and equipment related to its exploration and development activities, which are typically classified as operating leases under the provisions of the standard. ROU assets are reflected within “Deferred charges and other assets” on the Company’s consolidated balance sheet, and the associated operating lease liabilities are reflected within “Other current liabilities” and “Other noncurrent liabilities,” as applicable.

Operating lease expense associated with ROU assets is recognized on a straight-line basis over the lease term. Lease expense is reflected on the statement of consolidated operations commensurate with the leased activities and nature of the services performed. Fixed operating lease expense was $55 million for the first quarter of 2019.

New Pronouncements Issued But Not Yet Adopted

New Pronouncements Issued But Not Yet Adopted

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments-Credit Losses.” The standard changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, held-to-maturity debt securities and loans, and requires entities to use a new forward-looking expected loss model that will result in the earlier recognition of allowance for losses. This update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Entities will apply the standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The Company is evaluating the new guidance and does not believe this standard will have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-13, “Disclosure Framework: Changes to the Disclosure Requirements for Fair Value Measurement,” which changes the disclosure requirements for fair value measurements by removing, adding, and modifying certain disclosures. ASU 2018-13 is effective for financial statements issued for annual periods beginning after December 15, 2019, and interim periods within those annual periods. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-14, “Disclosure Framework: Changes to the Disclosure Requirements for Defined Benefit Plans,” which eliminates, modifies, and adds disclosure requirements for defined benefit plans. The ASU is effective for financial statements issued for fiscal years ending after December 15, 2020. Early adoption is permitted. The Company is currently evaluating the impact of adoption of this ASU on its related disclosures and does not expect it to have a material impact on its financial statements.

In August 2018, the FASB issued ASU 2018-15, “Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract.” This pronouncement clarifies the requirements for capitalizing implementation costs in cloud computing arrangements and aligns them with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. This pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted, including adoption in any interim period for which financial statements have not been issued. The Company is currently evaluating the impact of adoption of this ASU on its consolidated financial statements and does not expect it to have a material impact.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

3 Months Ended

Mar. 31, 2019

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 first quarters of 2019 and 2018:

	Quarter Ended March 31,
	2019		2018
	(In millions)
Oil and Gas Property:
Proved	$	—	$	—
Unproved	23		16

Schedule of Weighted Average Lease Term and Discount Rate Related to Leases

The following table represents the Company’s weighted average lease term and discount rate as of March 31, 2019:

	Operating Leases		Finance Leases
Weighted average remaining lease term	3.4 years		8.7 years
Weighted average discount rate	4.3	%	4.3	%

Operating Lease, Liability, Maturity

The undiscounted future minimum lease payments reconciled to the carrying value of the lease liabilities as of March 31, 2019 were as follows:

Net Minimum Commitments	Operating Leases(1)			Finance Leases(2)
	(In millions)
2019	$	159		$	22
2020	111			13
2021	46			3
2022	40			3
2023	24			3
Thereafter	41			39
Total future minimum lease payments	421			83
Less: imputed interest	(34		)	(15		)
Total lease liabilities	387			68
Current portion	(187		)	(30		)
Non-current portion	$	200		$	38

(1) Amounts included for drilling rig and related operational equipment obligations represent future payments associated with oil and gas operations gross of amounts billable to partners and other working interest owners. Such payments may be capitalized as a component of oil and gas properties, and either depreciated, impaired, or written off as exploration expense.

(2)

Amounts represent the Company’s finance lease obligation related to physical power generators being leased on a one-year term with the right to purchase (entered into during the first quarter of 2019) and a separate lease for the Company’s Midland, Texas regional office building.

Finance Lease, Liability, Maturity

The undiscounted future minimum lease payments reconciled to the carrying value of the lease liabilities as of March 31, 2019 were as follows:

Net Minimum Commitments	Operating Leases(1)			Finance Leases(2)
	(In millions)
2019	$	159		$	22
2020	111			13
2021	46			3
2022	40			3
2023	24			3
Thereafter	41			39
Total future minimum lease payments	421			83
Less: imputed interest	(34		)	(15		)
Total lease liabilities	387			68
Current portion	(187		)	(30		)
Non-current portion	$	200		$	38

(1) Amounts included for drilling rig and related operational equipment obligations represent future payments associated with oil and gas operations gross of amounts billable to partners and other working interest owners. Such payments may be capitalized as a component of oil and gas properties, and either depreciated, impaired, or written off as exploration expense.

(2)

Amounts represent the Company’s finance lease obligation related to physical power generators being leased on a one-year term with the right to purchase (entered into during the first quarter of 2019) and a separate lease for the Company’s Midland, Texas regional office building.

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of commodity derivative positions

As of March 31, 2019, Apache had the following open crude oil financial basis swap contracts:

Production Period	Settlement Index	Mbbls	Weighted Average Price Differential
April—September 2019	Midland-WTI/Cushing-WTI	4,941	$(8.60)
October—December 2019	Midland-WTI/Cushing-WTI	1,380	$(3.72)

As of March 31, 2019, Apache had the following open natural gas costless collar contracts:

Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Floor Price	Weighted Average Ceiling Price
April—June 2019	NYMEX Henry Hub	9,100	$3.00	$3.92

As of March 31, 2019, Apache had the following open natural gas financial basis swap contracts:

		Basis Swap Purchased		Basis Swap Sold
Production Period	Settlement Index	MMBtu (in 000’s)	Weighted Average Price Differential	MMBtu (in 000’s)	Weighted Average Price Differential
April—June 2019	NYMEX Henry Hub/Waha	10,920	$(1.74)	16,380	$(0.53)
April—June 2019	NYMEX Henry Hub/EP Permian	—	—	10,920	$(1.58)
April—December 2019	NYMEX Henry Hub/Waha	—	—	11,000	$(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)
March 31, 2019
Assets:
Commodity Derivative Instruments	$	—	$	50	$	—	$	50	$	(14	)	$	36
Foreign Currency Derivative Instruments	—		1		—		1		—			1
Liabilities:
Commodity Derivative Instruments	—		46		—		46		(14		)	32
Interest Rate Derivative Instruments	—		6		—		6		—			6
December 31, 2018
Assets:
Commodity Derivative Instruments	$	—	$	69	$	—	$	69	$	(14	)	$	55
Liabilities:
Commodity Derivative Instruments	—		25		—		25		(14		)	11

(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)
March 31, 2019
Assets:
Commodity Derivative Instruments	$	—	$	50	$	—	$	50	$	(14	)	$	36
Foreign Currency Derivative Instruments	—		1		—		1		—			1
Liabilities:
Commodity Derivative Instruments	—		46		—		46		(14		)	32
Interest Rate Derivative Instruments	—		6		—		6		—			6
December 31, 2018
Assets:
Commodity Derivative Instruments	$	—	$	69	$	—	$	69	$	(14	)	$	55
Liabilities:
Commodity Derivative Instruments	—		25		—		25		(14		)	11

(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:

	March 31, 2019		December 31, 2018
	(In millions)
Current Assets: Prepaid assets and other	$	37	$	55
Total Assets	$	37	$	55
Current Liabilities: Other current liabilities	$	38	$	11
Total Liabilities	$	38	$	11

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 March 31,
	2019			2018
	(In millions)
Realized gain (loss):
Derivative settlements, realized gain (loss)	$	15		$	(42	)
Amortization of put premium, realized loss	—			(5		)
Unrealized gain (loss)	(45		)	49
Derivative instrument gains (losses), net	$	(30	)	$	2

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EQUITY METHOD INTERESTS (Tables)

3 Months Ended

Mar. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Summary of equity method investment information

The following table presents the activity in Apache’s equity method interests for the three months ended March 31, 2019:

	Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Total
	(In millions)
Balance at December 31, 2018	$	91	$	—	$	91
Acquisitions	—		52		52
Contributions	66		—		66
Balance at March 31, 2019	$	157	$	52	$	209

	March 31, 2019				December 31, 2018
	Interest		Amount		Interest		Amount
	($ in millions)
Gulf Coast Express Pipeline LLC	15.0	%	$	157	15.0	%	$	91
EPIC Crude Holdings, LP	15.0	%	52		—		—
			$	209			$	91

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OTHER CURRENT LIABILITIES (Tables)

3 Months Ended

Mar. 31, 2019

Payables and Accruals [Abstract]

Detail of Other Current Liabilities

The following table provides detail of the Company’s other current liabilities as of March 31, 2019 and December 31, 2018:

	March 31, 2019		December 31, 2018
	(In millions)
Accrued operating expenses	$	72	$	65
Accrued exploration and development	552		667
Accrued gathering, processing, and transmission - Altus	63		81
Accrued compensation and benefits	96		177
Accrued interest	121		137
Accrued income taxes	60		58
Current asset retirement obligation	66		66
Current operating lease liability	187		—
Other	139		90
Total other current liabilities	$	1,356	$	1,341

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ASSET RETIREMENT OBLIGATION (Tables)

3 Months Ended

Mar. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligation

The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the three-month period ended March 31, 2019:

	(In millions)
Asset retirement obligation at December 31, 2018	$	1,932
Liabilities incurred	3
Liabilities settled	(11		)
Liabilities held for sale	(6		)
Accretion expense	27
Asset retirement obligation at March 31, 2019	1,945
Less current portion	(66		)
Asset retirement obligation, long-term	$	1,879

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DEBT AND FINANCING COSTS (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Schedule of Debt

The following table presents the carrying value of the Company’s debt as of March 31, 2019 and December 31, 2018:

	March 31, 2019			December 31, 2018
	(In millions)
Notes and debentures before unamortized discount and debt issuance costs	$	8,299		$	8,299
Commercial paper	159			—
Finance lease obligations	68			40
Unamortized discount	(43		)	(44		)
Debt issuance costs	(50		)	(51		)
Total debt	8,433			8,244
Current maturities	(339		)	(151		)
Long-term debt	$	8,094		$	8,093

Components of Financing Costs, Net

The following table presents the components of Apache’s financing costs, net:

	For the Quarter Ended March 31,
	2019			2018
	(In millions)
Interest expense	$	107		$	112
Amortization of deferred loan costs	2			5
Capitalized interest	(8		)	(12		)
Interest income	(4		)	(6		)
Financing costs, net	$	97		$	99

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CAPITAL STOCK (Tables)

3 Months Ended

Mar. 31, 2019

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 ended March 31, 2019 and 2018, is presented in the table below. 

	For the Quarter Ended March 31,
	2019							2018
	Loss			Shares	Per Share			Income		Shares	Per Share
	(In millions, except per share amounts)
Basic:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	382	$	0.38
Effect of Dilutive Securities:
Stock options and other	$	—		—	$	—		$	—	2	$	—
Diluted:
Income (loss) attributable to common stock	$	(47	)	376	$	(0.12	)	$	145	384	$	0.38

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BUSINESS SEGMENT INFORMATION (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Financial Segment Information

Financial information for each segment is presented below:

	Egypt(1)		North Sea		U.S.		Altus		Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2019
Oil revenues	$	514	$	300	$	496	$	—	$	—		$	1,310
Natural gas revenues	81		32		123		—		—			236
Natural gas liquids revenues	4		6		98		—		—			108
Oil and gas production revenues	599		338		717		—		—			1,654
Midstream service affiliate revenues	—		—		—		34		(34		)	—
Operating Expenses:
Lease operating expenses	118		72		176		—		(1		)	365
Gathering, processing, and transmission	12		12		81		16		(33		)	88
Taxes other than income	—		—		48		3		—			51
Exploration	32		1		33		—		3			69
Depreciation, depletion, and amortization	188		99		352		7		—			646
Asset retirement obligation accretion	—		19		8		—		—			27
	350		203		698		26		(31		)	1,246
Operating Income (Loss)(3)	$	249	$	135	$	19	$	8	$	(3	)	408
Other Income (Expense):
Gain on divestitures												3
Derivative instrument losses, net												(30		)
Other(4)												8
General and administrative												(123		)
Transaction, reorganization, and separation												(4		)
Financing costs, net												(97		)
Income Before Income Taxes												$	165
Total Assets(5)	$	4,065	$	2,601	$	13,205	$	1,825	$	55		$	21,751

	Egypt(1)		North Sea		U.S.		Altus			Intersegment Eliminations & Other			Total(2)
	Upstream						Midstream
	(In millions)
For the Quarter Ended March 31, 2018
Oil revenues	$	569	$	271	$	553	$	—		$	—		$	1,393
Natural gas revenues	88		24		110		—			—			222
Natural gas liquids revenues	3		4		111		—			—			118
Oil and gas production revenues	660		299		774		—			—			1,733
Midstream service affiliate revenues	—		—		—		12			(12		)	—
Operating Expenses:
Lease operating expenses	98		93		158		—			—			349
Gathering, processing, and transmission	12		10		65		11			(12		)	86
Taxes other than income	—		—		52		3			—			55
Exploration	28		14		33		—			1			76
Depreciation, depletion, and amortization	186		95		269		3			—			553
Asset retirement obligation accretion	—		19		8		—			—			27
	324		231		585		17			(11		)	1,146
Operating Income (Loss)(3)	$	336	$	68	$	189	$	(5	)	$	(1	)	587
Other Income (Expense):
Gain on divestitures													7
Derivative instrument gains, net													2
Other(4)													5
General and administrative													(114		)
Financing costs, net													(99		)
Income Before Income Taxes													$	388
Total Assets(5)	$	4,813	$	3,009	$	13,106	$	821		$	42		$	21,791

(1) Includes revenue from non-customers of $107 million, $11 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2019, and $139 million, $15 million, and $1 million for oil, natural gas, and natural gas liquids, respectively, for the first quarter of 2018.

(2) Includes a noncontrolling interest in Egypt for the 2019 and 2018 periods, and Altus for the 2019 period.

(3) The operating income of U.S. and North Sea includes leasehold and unproved impairments totaling $21 million and $2 million, respectively, for the first quarter of 2019. The operating income of U.S. includes leasehold and unproved impairments totaling $16 million for the first quarter of 2018.

(4) Included in Other are sales proceeds related to U.S. third-party purchased oil and gas totaling $24 million and $104 million for the periods ending March 31, 2019 and 2018, respectively, which are determined to be revenue from customers.

(5)

Intercompany balances are excluded from total assets.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 USD ($) $ / MMBTU	Mar. 31, 2018 USD ($)	Jan. 01, 2019 USD ($)	Dec. 31, 2018 USD ($)
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments	$ 0	$ 0
Oil and gas production revenues	1,654,000,000	1,733,000,000
Cost of oil and gas purchased	$ 88,000,000	86,000,000
Maximum percentage of production available to contract partners	40.00%
Revenue from customers	$ 1,600,000,000	1,700,000,000
Revenue from non-customer	119,000,000	155,000,000
Receivables from contracts with customer, net	1,000,000,000.0			$ 1,000,000,000
Fixed operating lease expenses	55,000,000
Variable lease payment	17,000,000
Other noncurrent liabilities	(425,000,000)			(219,000,000)
Long-term debt	8,094,000,000			$ 8,093,000,000
Oil and Gas Properties, Proved
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments	0	0
Oil and Gas Properties, Unproved
Schedule Of Significant Accounting Policies [Line Items]
Asset impairments	$ 23,000,000	16,000,000
Minimum
Schedule Of Significant Accounting Policies [Line Items]
Percentage of voting interests acquired	50.00%
Maximum
Schedule Of Significant Accounting Policies [Line Items]
Percentage of voting interests acquired	50.00%
Midland-WTI/Cushing-WTI | Crude Oil | Minimum
Schedule Of Significant Accounting Policies [Line Items]
Oil and gas pricing formula sliding scale | $ / MMBTU	1.50
Midland-WTI/Cushing-WTI | Crude Oil | Maximum
Schedule Of Significant Accounting Policies [Line Items]
Oil and gas pricing formula sliding scale | $ / MMBTU	2.65
Oil and Gas, Purchased
Schedule Of Significant Accounting Policies [Line Items]
Oil and gas production revenues	$ 24,000,000	104,000,000
Cost of oil and gas purchased	$ 22,000,000	$ 105,000,000
Accounting Standards Update 2016-02
Schedule Of Significant Accounting Policies [Line Items]
Other noncurrent liabilities			$ 39,000,000
Long-term debt			$ 39,000,000
Altus Midstream Company
Schedule Of Significant Accounting Policies [Line Items]
Ownership percentage by noncontrolling owners	21.00%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Company's Weighted Average Lease Term and Discount Rate related to Leases (Details)	Mar. 31, 2019
Leases [Abstract]
Operating leases, weighted average remaining lease term	3 years 4 months 24 days
Finance leases, weighted average remaining lease term	8 years 8 months 12 days
Operating leases, weighted average discount rate	4.30%
Finance leases, weighted average discount rate	4.30%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Operating Leases
2019	$ 159
2020	111
2021	46
2022	40
2023	24
Thereafter	41
Total future minimum lease payments	421
Less: imputed interest	(34)
Total lease liabilities	387
Current portion	(187)
Non-current portion	200
Finance Leases
2019	22
2020	13
2021	3
2022	3
2023	3
Thereafter	39
Total future minimum lease payments	83
Less: imputed interest	(15)
Total lease liabilities	68	$ 1
Current portion	(30)
Non-current portion	$ 38

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ACQUISITIONS AND DIVESTITURES (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	May 02, 2019	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Business Acquisition [Line Items]
Leasehold and property acquisitions		$ 15	$ 12
Assets held for sale		217		$ 0
U.S. onshore regions
Business Acquisition [Line Items]
Leasehold and property acquisitions		15	12
Permian region
Business Acquisition [Line Items]
Proceeds from sale of non-core assets		9	9
Gains on sale of non-core assets		3	$ 7
Disposal Group, Held-for-sale, Not Discontinued Operations | Oklahoma
Business Acquisition [Line Items]
Non-core assets, selling price		245
Assets held for sale		217
Liability held for sale		$ 6
Subsequent Event | South Texas
Business Acquisition [Line Items]
Proceeds from sale of non-core assets	$ 43

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CAPITALIZED EXPLORATORY WELL COSTS (Details) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Capitalized exploratory well costs	$ 123,000,000	$ 159,000,000
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 0

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Derivative Instruments (Detail) - 3 months ended Mar. 31, 2019 bbl in Thousands, MMBTU in Thousands, £ in Millions, $ in Millions	USD ($) MMBTU Counterparty $ / MMBTU $ / bbl bbl	GBP (£) $ / MMBTU $ / bbl
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of derivative counterparties | Counterparty	14
Put Options | April—September 2019 | Crude Oil | Midland-WTI/Cushing-WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl	4,941
Weighted Average Price Differential | $ / bbl	(8.60)	(8.60)
Put Options | October—December 2019 | Crude Oil | Midland-WTI/Cushing-WTI
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, volume | bbl	1,380
Weighted Average Price Differential | $ / bbl	(3.72)	(3.72)
Collars | April—June 2019 | Natural Gas | NYMEX Henry Hub/Waha
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, nonmonetary notional amount, energy | MMBTU	9,100
Derivative, weighted average floor price (USD per bbl)	3.00	3.00
Derivative, weighted average ceiling price (USD per bbl)	3.92	3.92
Collars | January—December 2019
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, weighted average floor price (USD per bbl)	1.20	1.20
Derivative, weighted average ceiling price (USD per bbl)	1.35	1.35
Derivative, notional amount | £		£ 12.5
Basis Swap Purchased | April—June 2019 | Natural Gas | NYMEX Henry Hub/Waha
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	(1.74)	(1.74)
Derivative, nonmonetary notional amount, energy | MMBTU	10,920
Basis Swap Purchased | April—June 2019 | Natural Gas | NYMEX Henry Hub/EP Permian
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	0	0
Derivative, nonmonetary notional amount, energy | MMBTU	0
Basis Swap Purchased | April—December 2019 | Natural Gas | NYMEX Henry Hub/Waha
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	0	0
Derivative, nonmonetary notional amount, energy | MMBTU	0
Basis Swap Sold | April—June 2019 | Natural Gas | NYMEX Henry Hub/Waha
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	(0.53)	(0.53)
Derivative, nonmonetary notional amount, energy | MMBTU	16,380
Basis Swap Sold | April—June 2019 | Natural Gas | NYMEX Henry Hub/EP Permian
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	(1.58)	(1.58)
Derivative, nonmonetary notional amount, energy | MMBTU	10,920
Basis Swap Sold | April—December 2019 | Natural Gas | NYMEX Henry Hub/Waha
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Weighted Average Price Differential	(0.45)	(0.45)
Derivative, nonmonetary notional amount, energy | MMBTU	11,000
Treasury lock contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, notional amount | $	$ 400

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Assets and Liabilities Measured at Fair Value (Details) - Recurring - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivative [Line Items]
Derivative asset	$ 37	$ 55
Derivative liability	38	11
Commodity Derivative Instruments
Derivative [Line Items]
Derivative asset, fair value	50	69
Derivative asset, netting	(14)	(14)
Derivative asset	36	55
Derivative liability, fair value	46	25
Derivative liability, netting	(14)	(14)
Derivative liability	32	11
Commodity Derivative Instruments | Quoted Price in Active Markets (Level 1)
Derivative [Line Items]
Derivative asset, fair value	0	0
Derivative liability, fair value	0	0
Commodity Derivative Instruments | Significant Other Inputs (Level 2)
Derivative [Line Items]
Derivative asset, fair value	50	69
Derivative liability, fair value	46	25
Commodity Derivative Instruments | Significant Unobservable Inputs (Level 3)
Derivative [Line Items]
Derivative asset, fair value	0	0
Derivative liability, fair value	0	$ 0
Foreign Currency Derivative Instruments
Derivative [Line Items]
Derivative asset, fair value	1
Derivative asset, netting	0
Derivative asset	1
Foreign Currency Derivative Instruments | Quoted Price in Active Markets (Level 1)
Derivative [Line Items]
Derivative asset, fair value	0
Foreign Currency Derivative Instruments | Significant Other Inputs (Level 2)
Derivative [Line Items]
Derivative asset, fair value	1
Foreign Currency Derivative Instruments | Significant Unobservable Inputs (Level 3)
Derivative [Line Items]
Derivative asset, fair value	0
Interest Rate Derivative Instruments
Derivative [Line Items]
Derivative liability, fair value	6
Derivative liability, netting	0
Derivative liability	6
Interest Rate Derivative Instruments | Quoted Price in Active Markets (Level 1)
Derivative [Line Items]
Derivative liability, fair value	0
Interest Rate Derivative Instruments | Significant Other Inputs (Level 2)
Derivative [Line Items]
Derivative liability, fair value	6
Interest Rate Derivative Instruments | Significant Unobservable Inputs (Level 3)
Derivative [Line Items]
Derivative liability, fair value	$ 0

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Assets and Liabilities and Locations on Consolidated Balance Sheet (Details) - Recurring - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative asset	$ 37	$ 55
Derivative liability	38	11
Current Assets: Prepaid assets and other
Derivatives, Fair Value [Line Items]
Derivative asset	37	55
Current Liabilities: Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability	38	11
Commodity Derivative Instruments
Derivatives, Fair Value [Line Items]
Derivative asset	36	55
Derivative liability	$ 32	$ 11

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Schedule of Derivative Activities Recorded in the Statement of Consolidated Operations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Realized gain (loss):
Unrealized gain (loss)	$ (45)	$ 49
Not Designated as Hedging Instrument
Realized gain (loss):
Derivative settlements, realized gain (loss)	15	(42)
Amortization of put premium, realized loss	0	(5)
Unrealized gain (loss)	(45)	49
Derivative instrument gains (losses), net	$ (30)	$ 2

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EQUITY METHOD INTERESTS - Summary of Investments (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Equity method interests	$ 209	$ 121
Altus Midstream Company
Schedule of Equity Method Investments [Line Items]
Equity method interests	$ 209	$ 91
Altus Midstream Company | Gulf Coast Express Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Interest	15.00%	15.00%
Equity method interests	$ 157	$ 91
Altus Midstream Company | EPIC Crude Holdings, LP
Schedule of Equity Method Investments [Line Items]
Interest	15.00%	0.00%
Equity method interests	$ 52	$ 0

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EQUITY METHOD INTERESTS - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount and underlying equity amount	$ 1,000,000	$ 6,000,000
Equity method interests	209,000,000	$ 121,000,000
Marine Well Containment Company
Schedule of Equity Method Investments [Line Items]
Equity method interests	30,000,000
Gain (loss) on disposal of investment	$ 0

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EQUITY METHOD INTERESTS - Rollforward Activity (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Movement In Equity Method Interests [Roll Forward]
Balance at December 31, 2018	$ 121
Acquisitions	118	$ 0
Balance at March 31, 2019	209
Altus Midstream Company
Movement In Equity Method Interests [Roll Forward]
Balance at December 31, 2018	91
Acquisitions	52
Contributions	66
Balance at March 31, 2019	209
Altus Midstream Company | Gulf Coast Express Pipeline LLC
Movement In Equity Method Interests [Roll Forward]
Balance at December 31, 2018	91
Acquisitions	0
Contributions	66
Balance at March 31, 2019	157
Altus Midstream Company | EPIC Crude Holdings, LP
Movement In Equity Method Interests [Roll Forward]
Balance at December 31, 2018	0
Acquisitions	52
Contributions	0
Balance at March 31, 2019	$ 52

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OTHER CURRENT LIABILITIES (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Payables and Accruals [Abstract]
Accrued operating expenses	$ 72	$ 65
Accrued exploration and development	552	667
Accrued gathering, processing, and transmission - Altus	63	81
Accrued compensation and benefits	96	177
Accrued interest	121	137
Accrued income taxes	60	58
Current asset retirement obligation	66	66
Current operating lease liability	187
Other	139	90
Total other current liabilities	$ 1,356	$ 1,341

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ASSET RETIREMENT OBLIGATION (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation at the beginning of period	$ 1,932
Liabilities incurred	3
Liabilities settled	(11)
Liabilities held for sale	(6)
Accretion expense	27
Asset retirement obligation at the end of period	1,945
Less current portion	(66)	$ (66)
Asset retirement obligation, long-term	$ 1,879	$ 1,866

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DEBT AND FINANCING COSTS - Schedule of Debt (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Finance lease obligations	$ 68	$ 1
Capital lease obligations		40
Unamortized discount	(43)	(44)
Debt issuance costs	(50)	(51)
Total debt	8,433	8,244
Current maturities	(339)	(151)
Long-term debt	8,094	8,093
Unsecured Debt | Commercial Paper
Debt Instrument [Line Items]
Long-term debt, gross	159	0
Notes And Debentures | Unsecured Debt
Debt Instrument [Line Items]
Long-term debt, gross	$ 8,299	$ 8,299

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DEBT AND FINANCING COSTS - Additional Information (Detail) £ in Millions	1 Months Ended		3 Months Ended
	Mar. 31, 2019 USD ($)	Nov. 30, 2018 USD ($) contract	Mar. 31, 2019 USD ($)	Mar. 31, 2019 GBP (£)	Mar. 01, 2019 USD ($)	Feb. 28, 2019 USD ($)	Dec. 31, 2018 USD ($)	Mar. 31, 2018 USD ($)
Debt Instrument [Line Items]
Finance lease obligations, current	$ 30,000,000		$ 30,000,000
Finance lease obligations	68,000,000		68,000,000				$ 1,000,000
Available commercial paper	$ 3,500,000,000		3,500,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, committed amount								$ 4,000,000,000.0
Extended financing agreement term	1 year
Credit facility maximum borrowing capacity	$ 5,000,000,000.0		5,000,000,000.0
Letters of credit outstanding, amount	0		0
Letter of Credit
Debt Instrument [Line Items]
Line of credit facility, committed amount	2,080,000,000.00		2,080,000,000.00
Credit facility maximum borrowing capacity	3,000,000,000.0		3,000,000,000.0
Line of credit facility aggregate commitment amount | £				£ 3.1
Notes And Debentures
Debt Instrument [Line Items]
Debt instrument, fair value	8,300,000,000		8,300,000,000				7,800,000,000
Unsecured Debt | 6.9% senior notes due September 15, 2018
Debt Instrument [Line Items]
Debt instrument, face amount	$ 150,000,000		$ 150,000,000				$ 150,000,000
Debt instrument, stated interest rate	7.625%		7.625%	7.625%			7.625%
Unsecured Debt | Notes And Debentures
Debt Instrument [Line Items]
Long-term debt, gross	$ 8,299,000,000		$ 8,299,000,000				$ 8,299,000,000
Altus Midstream LP | Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Extended financing agreement term		1 year
Credit facility maximum borrowing capacity		$ 450,000,000			$ 1,500,000,000	$ 800,000,000
Line of credit facility, number of extension options | contract		2
Debt covenant, minimum consolidated net income for three consecutive calendar months		$ 175,000,000
Debt covenant, minimum additional capital raised		$ 250,000,000
Borrowings on line of credit	0		$ 0
Altus Midstream LP | Line of Credit | Letter of Credit
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity						100,000,000
Altus Midstream LP | Line of Credit | Swingline Loan Subfacility
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity						$ 100,000,000
Commercial Paper
Debt Instrument [Line Items]
Period for borrowing funds			270 days
Commercial Paper | Unsecured Debt
Debt Instrument [Line Items]
Long-term debt, gross	$ 159,000,000		$ 159,000,000				$ 0

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DEBT AND FINANCING COSTS - Components of Financing Costs, Net (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Debt Disclosure [Abstract]
Interest expense	$ 107	$ 112
Amortization of deferred loan costs	2	5
Capitalized interest	(8)	(12)
Interest income	(4)	(6)
Financing costs, net	$ 97	$ 99

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COMMITMENTS AND CONTINGENCIES (Detail) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)	Apr. 30, 2017 AUD ($)
Commitment And Contingencies [Line Items]
Accrued liability for legal contingencies	$ 35,000,000
Undiscounted reserve for environmental remediation	5,000,000
Apollo Exploration Lawsuit
Commitment And Contingencies [Line Items]
Plaintiffs alleged damages	200,000,000
Apollo Exploration Lawsuit | Minimum
Commitment And Contingencies [Line Items]
Plaintiffs alleged damages		$ 1,100,000,000
Australian Operations Divestiture Dispute | Apache Australia Operation
Commitment And Contingencies [Line Items]
Gain contingency, unrecorded amount				$ 80
Loss contingency, estimated of possible loss amount			$ 200,000,000
Castex Lawsuit
Commitment And Contingencies [Line Items]
Plaintiffs alleged damages	60,000,000
Loss contingency, estimated of possible loss amount	$ 200,000,000

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CAPITAL STOCK - Net Income (loss) Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Basic:
Income (loss) attributable to common stock	$ (47)	$ 145
Income (loss) attributable to common stock, shares	376	382
Basic net income (loss) per share (in USD per share)	$ (0.12)	$ 0.38
Effect of Dilutive Securities:
Stock options and other (in shares)	0	2
Diluted:
Income (loss) attributable to common stock	$ (47)	$ 145
Income (loss) attributable to common stock, shares	376	384
Diluted net income (loss) per share (in USD per share)	$ (0.12)	$ 0.38

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CAPITAL STOCK - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		70 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2014
Equity [Abstract]
Options and restricted stock, anti-dilutive (in shares)	5,500,000	6,700,000
Payments of dividend on common stock	$ 94	$ 95
Number of shares authorized to be repurchased (in shares)				40,000,000	40,000,000
Number of shares repurchased during period (in shares)	0		40,000,000
Average price of shares repurchased during period (in USD per share)			$ 79.18

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BUSINESS SEGMENT INFORMATION (Detail)	3 Months Ended
	Mar. 31, 2019 USD ($) Segment	Mar. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)
Segment Reporting [Abstract]
Number of reporting segments | Segment	3
Segment Reporting Information [Line Items]
Oil and gas production revenues	$ 1,654,000,000	$ 1,733,000,000
Lease operating expenses	365,000,000	349,000,000
Gathering, processing, and transmission	88,000,000	86,000,000
Taxes other than income	51,000,000	55,000,000
Exploration	69,000,000	76,000,000
Depreciation, depletion, and amortization	646,000,000	553,000,000
Asset retirement obligation accretion	27,000,000	27,000,000
Operating expenses	1,246,000,000	1,146,000,000
Operating Income (Loss)	408,000,000	587,000,000
Other Income (Expense):
Gain on divestitures	3,000,000	7,000,000
Derivative instrument gains (losses), net	(30,000,000)	2,000,000
Other	8,000,000	5,000,000
General and administrative	(123,000,000)	(114,000,000)
Transaction, reorganization, and separation	(4,000,000)	0
Financing costs, net	(97,000,000)	(99,000,000)
NET INCOME BEFORE INCOME TAXES	165,000,000	388,000,000
Total Assets	21,751,000,000	21,791,000,000	$ 21,582,000,000
Revenue from non-customer	119,000,000	155,000,000
Asset impairments	0	0
Operating Segments | Egypt
Segment Reporting Information [Line Items]
Oil and gas production revenues	599,000,000	660,000,000
Lease operating expenses	118,000,000	98,000,000
Gathering, processing, and transmission	12,000,000	12,000,000
Taxes other than income	0	0
Exploration	32,000,000	28,000,000
Depreciation, depletion, and amortization	188,000,000	186,000,000
Asset retirement obligation accretion	0	0
Operating expenses	350,000,000	324,000,000
Operating Income (Loss)	249,000,000	336,000,000
Other Income (Expense):
Total Assets	4,065,000,000	4,813,000,000
Operating Segments | North Sea
Segment Reporting Information [Line Items]
Oil and gas production revenues	338,000,000	299,000,000
Lease operating expenses	72,000,000	93,000,000
Gathering, processing, and transmission	12,000,000	10,000,000
Taxes other than income	0	0
Exploration	1,000,000	14,000,000
Depreciation, depletion, and amortization	99,000,000	95,000,000
Asset retirement obligation accretion	19,000,000	19,000,000
Operating expenses	203,000,000	231,000,000
Operating Income (Loss)	135,000,000	68,000,000
Other Income (Expense):
Total Assets	2,601,000,000	3,009,000,000
Asset impairments	2,000,000
Operating Segments | U.S.
Segment Reporting Information [Line Items]
Oil and gas production revenues	717,000,000	774,000,000
Lease operating expenses	176,000,000	158,000,000
Gathering, processing, and transmission	81,000,000	65,000,000
Taxes other than income	48,000,000	52,000,000
Exploration	33,000,000	33,000,000
Depreciation, depletion, and amortization	352,000,000	269,000,000
Asset retirement obligation accretion	8,000,000	8,000,000
Operating expenses	698,000,000	585,000,000
Operating Income (Loss)	19,000,000	189,000,000
Other Income (Expense):
Total Assets	13,205,000,000	13,106,000,000
Asset impairments	21,000,000	16,000,000
Operating Segments | Altus Midstream
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Lease operating expenses	0	0
Gathering, processing, and transmission	16,000,000	11,000,000
Taxes other than income	3,000,000	3,000,000
Exploration	0	0
Depreciation, depletion, and amortization	7,000,000	3,000,000
Asset retirement obligation accretion	0	0
Operating expenses	26,000,000	17,000,000
Operating Income (Loss)	8,000,000	(5,000,000)
Other Income (Expense):
Total Assets	1,825,000,000	821,000,000
Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Oil and gas production revenues	(34,000,000)	(12,000,000)
Lease operating expenses	(1,000,000)	0
Gathering, processing, and transmission	(33,000,000)	(12,000,000)
Taxes other than income	0	0
Exploration	3,000,000	1,000,000
Depreciation, depletion, and amortization	0	0
Asset retirement obligation accretion	0	0
Operating expenses	(31,000,000)	(11,000,000)
Operating Income (Loss)	(3,000,000)	(1,000,000)
Other Income (Expense):
Total Assets	55,000,000	42,000,000
Intersegment Eliminations & Other | Egypt
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Intersegment Eliminations & Other | North Sea
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Intersegment Eliminations & Other | U.S.
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Intersegment Eliminations & Other | Altus Midstream
Segment Reporting Information [Line Items]
Oil and gas production revenues	34,000,000	12,000,000
Oil and Gas, Purchased
Segment Reporting Information [Line Items]
Oil and gas production revenues	24,000,000	104,000,000
Gathering, processing, and transmission	22,000,000	105,000,000
Oil
Segment Reporting Information [Line Items]
Oil and gas production revenues	1,310,000,000	1,393,000,000
Other Income (Expense):
Revenue from non-customer	107,000,000	139,000,000
Oil | Operating Segments | Egypt
Segment Reporting Information [Line Items]
Oil and gas production revenues	514,000,000	569,000,000
Oil | Operating Segments | North Sea
Segment Reporting Information [Line Items]
Oil and gas production revenues	300,000,000	271,000,000
Oil | Operating Segments | U.S.
Segment Reporting Information [Line Items]
Oil and gas production revenues	496,000,000	553,000,000
Oil | Operating Segments | Altus Midstream
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Oil | Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Natural Gas
Segment Reporting Information [Line Items]
Oil and gas production revenues	236,000,000	222,000,000
Other Income (Expense):
Revenue from non-customer	11,000,000	15,000,000
Natural Gas | Operating Segments | Egypt
Segment Reporting Information [Line Items]
Oil and gas production revenues	81,000,000	88,000,000
Natural Gas | Operating Segments | North Sea
Segment Reporting Information [Line Items]
Oil and gas production revenues	32,000,000	24,000,000
Natural Gas | Operating Segments | U.S.
Segment Reporting Information [Line Items]
Oil and gas production revenues	123,000,000	110,000,000
Natural Gas | Operating Segments | Altus Midstream
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Natural Gas | Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Natural gas liquids
Segment Reporting Information [Line Items]
Oil and gas production revenues	108,000,000	118,000,000
Other Income (Expense):
Revenue from non-customer	1,000,000	1,000,000
Natural gas liquids | Operating Segments | Egypt
Segment Reporting Information [Line Items]
Oil and gas production revenues	4,000,000	3,000,000
Natural gas liquids | Operating Segments | North Sea
Segment Reporting Information [Line Items]
Oil and gas production revenues	6,000,000	4,000,000
Natural gas liquids | Operating Segments | U.S.
Segment Reporting Information [Line Items]
Oil and gas production revenues	98,000,000	111,000,000
Natural gas liquids | Operating Segments | Altus Midstream
Segment Reporting Information [Line Items]
Oil and gas production revenues	0	0
Natural gas liquids | Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Oil and gas production revenues	$ 0	$ 0