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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549 
FORM 10-Q 
(Mark One)  
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2022
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: 1-40144
APA CORPORATION
(Exact name of registrant as specified in its charter)
Delaware86-1430562
(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)
(713296-6000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock, $0.625 par valueAPANasdaq Global Select Market
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 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 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 filerAccelerated 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
Number of shares of registrant’s common stock outstanding as of April 30, 2022
338,232,412 




TABLE OF CONTENTS




FORWARD-LOOKING STATEMENTS AND RISKS
This report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act). All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding the Company’s 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 the Company’s examination of historical operating trends, the information that was used to prepare its estimate of proved reserves as of December 31, 2021, and other data in the Company’s 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,” “continue,” “seek,” “guidance,” “might,” “outlook,” “possibly,” “potential,” “prospect,” “should,” “would,” or similar terminology, but the absence of these words does not mean that a statement is not forward looking. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable under the circumstances, it can give no assurance that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from the Company’s expectations include, but are not limited to, its assumptions about:
the scope, duration, and reoccurrence of any epidemics or pandemics (including, specifically, the coronavirus disease 2019 (COVID-19) pandemic and any related variants) and the actions taken by third parties, including, but not limited to, governmental authorities, customers, contractors, and suppliers, in response to such epidemics or pandemics;
the mandate, availability, and effectiveness of vaccine programs and therapeutics related to the treatment of COVID-19;
the market prices of oil, natural gas, natural gas liquids (NGLs), and other products or services;
the Company’s 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, including market and macro-economic disruptions resulting from the Russian war in Ukraine;
the availability of capital resources;
capital expenditures and other contractual obligations;
currency exchange rates;
weather conditions;
inflation rates;
the availability of goods and services;
the impact of political pressure and the influence of environmental groups and other stakeholders on decisions and policies related to the industries in which the Company and its affiliates operate;
legislative, regulatory, or policy changes, including initiatives addressing the impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring, or water disposal;
the Company’s performance on environmental, social, and governance measures;
terrorism or cyberattacks;
the occurrence of property acquisitions or divestitures;
the integration of acquisitions;
the Company’s ability to access the capital markets;
market-related risks, such as general credit, liquidity, and interest-rate risks;



the Company’s expectations with respect to the new operating structure implemented pursuant to the Holding Company Reorganization (as defined in the Notes to the Company’s Consolidated Financial Statements set forth in Part I, Item 1—Financial Statements of this Quarterly Report on Form 10-Q) and the associated disclosure implications;
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 the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2021;
other risks and uncertainties disclosed in the Company’s first-quarter 2022 earnings release;
other factors disclosed under Part II, Item 1A—Risk Factors of this Quarterly Report on Form 10-Q; and
other factors disclosed in the other filings that the Company makes with the Securities and Exchange Commission.
Other factors or events that could cause the Company’s actual results to differ materially from the Company’s expectations may emerge from time to time, and it is not possible for the Company to predict all such factors or events. 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 these cautionary statements. All forward-looking statements speak only as of the date of this Quarterly Report on Form 10-Q. Except as required by law, the Company disclaims any obligation to update or revise these statements, whether based on changes in internal estimates or expectations, new information, future developments, or otherwise.



DEFINITIONS
All defined terms under Rule 4-10(a) of Regulation S-X shall have their statutorily prescribed meanings when used in this Quarterly Report on Form 10-Q. As used herein:
“3-D” means three-dimensional.
“4-D” means four-dimensional.
“b/d” means barrels of oil or NGLs per day.
“bbl” or “bbls” means barrel or barrels of oil or NGLs.
“bcf” means billion cubic feet of natural gas.
“bcf/d” means one bcf per day.
“boe” means barrel of oil equivalent, determined by using the ratio of one barrel of oil or NGLs to six Mcf of gas.
“boe/d” means boe per day.
“Btu” means a British thermal unit, a measure of heating value.
“Liquids” means oil and NGLs.
“LNG” means liquefied natural gas.
“Mb/d” means Mbbls per day.
“Mbbls” means thousand barrels of oil or NGLs.
“Mboe” means thousand boe.
“Mboe/d” means Mboe per day.
“Mcf” means thousand cubic feet of natural gas.
“Mcf/d” means Mcf per day.
“MMbbls” means million barrels of oil or NGLs.
“MMboe” means million boe.
“MMBtu” means million Btu.
“MMBtu/d” means MMBtu per day.
“MMcf” means million cubic feet of natural gas.
“MMcf/d” means MMcf per day.
“NGL” or “NGLs” means natural gas liquids, which are expressed in barrels.
“NYMEX” means New York Mercantile Exchange.
“oil” includes crude oil and condensate.
“PUD” means proved undeveloped.
“SEC” means the United States Securities and Exchange Commission.
“Tcf” means trillion cubic feet of natural gas.
“U.K.” means United Kingdom.
“U.S.” means United States.
With respect to information relating to the Company’s working interest in wells or acreage, “net” oil and gas wells or acreage is determined by multiplying gross wells or acreage by the Company’s working interest therein. Unless otherwise specified, all references to wells and acres are gross.
References to “APA,” the “Company,” “we,” “us,” and “our” refer to APA Corporation and its consolidated subsidiaries, including Apache Corporation, unless otherwise specifically stated. References to “Apache” refer to Apache Corporation, the Company’s wholly owned subsidiary, and its consolidated subsidiaries, unless otherwise specifically stated.



PART I – FINANCIAL INFORMATION
ITEM 1.    FINANCIAL STATEMENTS
APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED OPERATIONS
(Unaudited)
For the Quarter Ended
March 31,
20222021
 (In millions, except share data)
REVENUES AND OTHER:
Oil, natural gas, and natural gas liquids production revenues$2,320 $1,431 
Purchased oil and gas sales349 440 
Total revenues2,669 1,871 
Derivative instrument gains (losses), net(62)158 
Gain on divestitures, net1,176 2 
Other, net45 61 
3,828 2,092 
OPERATING EXPENSES:
Lease operating expenses344 264 
Gathering, processing, and transmission81 58 
Purchased oil and gas costs351 494 
Taxes other than income70 44 
Exploration42 49 
General and administrative156 83 
Transaction, reorganization, and separation14  
Depreciation, depletion, and amortization291 342 
Asset retirement obligation accretion29 28 
Financing costs, net152 110 
1,530 1,472 
NET INCOME BEFORE INCOME TAXES2,298 620 
Current income tax provision392 149 
Deferred income tax provision (benefit)(40)21 
NET INCOME INCLUDING NONCONTROLLING INTERESTS1,946 450 
Net income attributable to noncontrolling interest - Egypt119 42 
Net income attributable to noncontrolling interest - Altus14 1 
Net income (loss) attributable to Altus Preferred Unit limited partners(70)19 
NET INCOME ATTRIBUTABLE TO COMMON STOCK$1,883 $388 
NET INCOME PER COMMON SHARE:
Basic$5.44 $1.02 
Diluted$5.43 $1.02 
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic346 378 
Diluted347 379 

The accompanying notes to consolidated financial statements are an integral part of this statement.
1


APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (LOSS)
(Unaudited)
 
For the Quarter Ended
March 31,
 20222021
 (In millions)
NET INCOME INCLUDING NONCONTROLLING INTERESTS$1,946 $450 
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX:
Share of equity method interests other comprehensive income 1 
Pension and postretirement benefit plan(1) 
COMPREHENSIVE INCOME INCLUDING NONCONTROLLING INTERESTS1,945 451 
Comprehensive income attributable to noncontrolling interest - Egypt119 42 
Comprehensive income attributable to noncontrolling interest - Altus14 1 
Comprehensive income (loss) attributable to Altus Preferred Unit limited partners(70)19 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON STOCK$1,882 $389 

The accompanying notes to consolidated financial statements are an integral part of this statement.
2


APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS
(Unaudited)
For the Three Months Ended
March 31,
  20222021
 (In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income including noncontrolling interests$1,946 $450 
Adjustments to reconcile net income to net cash provided by operating activities:
Unrealized derivative instrument losses (gains), net57 (10)
Gain on divestitures, net(1,176)(2)
Exploratory dry hole expense and unproved leasehold impairments9 37 
Depreciation, depletion, and amortization291 342 
Asset retirement obligation accretion29 28 
Provision for (benefit from) deferred income taxes(40)21 
Loss on extinguishment of debt67  
Other, net(29)(20)
Changes in operating assets and liabilities:
Receivables(255)(168)
Inventories(43)(3)
Drilling advances and other current assets9 10 
Deferred charges and other long-term assets(13)(10)
Accounts payable18 75 
Accrued expenses18 (66)
Deferred credits and noncurrent liabilities3 (13)
NET CASH PROVIDED BY OPERATING ACTIVITIES891 671 
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to upstream oil and gas property(358)(253)
Additions to Altus gathering, processing, and transmission (GPT) facilities(1)(1)
Leasehold and property acquisitions(20)(2)
Contributions to Altus equity method interests(2)(21)
Proceeds from sale of oil and gas properties767 3 
Proceeds from sale of Kinetik shares224  
Deconsolidation of Altus cash and cash equivalents(143) 
Other, net(1)7 
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES466 (267)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from (payments on) Apache credit facility, net338 (85)
Proceeds from Altus credit facility, net 33 
Payments on Apache fixed-rate debt(1,370)(6)
Distributions to noncontrolling interest - Egypt(69)(40)
Distributions to Altus Preferred Unit limited partners(11)(11)
Treasury stock activity, net(261) 
Dividends paid to APA common stockholders(43)(9)
Other, net(9)(10)
NET CASH USED IN FINANCING ACTIVITIES(1,425)(128)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS(68)276 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR302 262 
CASH AND CASH EQUIVALENTS AT END OF PERIOD$234 $538 
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest$125 $113 
Income taxes paid, net of refunds305 124 

The accompanying notes to consolidated financial statements are an integral part of this statement.
3


APA CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
March 31,
2022(1)
December 31,
2021(1)
(In millions, except share data)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ($132 related to Altus VIE)
$234 $302 
Receivables, net of allowance of $111 and $109
1,630 1,394 
Other current assets (Note 5) ($9 related to Altus VIE)
729 684 
2,593 2,380 
PROPERTY AND EQUIPMENT:
Oil and gas properties40,553 40,749 
Gathering, processing, and transmission facilities ($209 related to Altus VIE)
464 673 
Other ($3 related to Altus VIE)
1,123 1,126 
Less: Accumulated depreciation, depletion, and amortization ($25 related to Altus VIE)
(34,058)(34,213)
8,082 8,335 
OTHER ASSETS:
Equity method interests (Note 6) ($1,365 related to Altus VIE)
576 1,365 
Decommissioning security for sold Gulf of Mexico properties (Note 11)
640 640 
Deferred charges and other ($6 related to Altus VIE)
585 583 
$12,476 $13,303 
LIABILITIES, NONCONTROLLING INTERESTS, AND EQUITY (DEFICIT)
CURRENT LIABILITIES:
Accounts payable ($12 related to Altus VIE)
$735 $731 
Current debt125 215 
Other current liabilities (Note 7) ($15 related to Altus VIE)
1,254 1,171 
2,114 2,117 
LONG-TERM DEBT (Note 9) ($657 related to Altus VIE)
5,764 7,295 
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes106 148 
Asset retirement obligation (Note 8) ($68 related to Altus VIE)
2,043 2,089 
Decommissioning contingency for sold Gulf of Mexico properties (Note 11)
1,086 1,086 
Other ($67 related to Altus VIE)
511 573 
3,746 3,896 
REDEEMABLE NONCONTROLLING INTEREST - ALTUS PREFERRED UNIT LIMITED PARTNERS (Note 12)
 712 
EQUITY (DEFICIT):
Common stock, $0.625 par, 860,000,000 shares authorized, 419,678,357 and 419,078,606 shares issued, respectively
262 262 
Paid-in capital11,600 11,645 
Accumulated deficit(7,605)(9,488)
Treasury stock, at cost, 79,375,295 and 72,147,841 shares, respectively
(4,296)(4,036)
Accumulated other comprehensive income21 22 
APA SHAREHOLDERS’ DEFICIT(18)(1,595)
Noncontrolling interest - Egypt870 820 
Noncontrolling interest - Altus 58 
TOTAL EQUITY (DEFICIT)852 (717)
$12,476 $13,303 
(1)    The Altus VIE amounts are disclosed as of December 31, 2021. All Altus balances were deconsolidated as of February 22, 2022. Refer to Note 1Summary of Significant Accounting Policies and Note 2—Acquisitions and Divestitures for further detail.

The accompanying notes to consolidated financial statements are an integral part of this statement.
4


APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CHANGES IN EQUITY (DEFICIT) AND NONCONTROLLING INTERESTS
(Unaudited)
Redeemable Noncontrolling Interest - Altus Preferred Unit Limited Partners(1)
Common
Stock
Paid-In
Capital
Accumulated DeficitTreasury
Stock
Accumulated
Other
Comprehensive
Income
APA SHAREHOLDERS’
DEFICIT
Noncontrolling
Interests(1)
TOTAL
EQUITY (DEFICIT)
(In millions)
For the Quarter Ended March 31, 2021
Balance at December 31, 2020$608 $262 $11,735 $(10,461)$(3,189)$14 $(1,639)$994 $(645)
Net income attributable to common stock— — — 388 — — 388 — 388 
Net income attributable to noncontrolling interest - Egypt— — — — — — — 42 42 
Net income attributable to noncontrolling interest - Altus— — — — — — — 1 1 
Net income attributable to Altus Preferred Unit holders19 — — — — — — — — 
Distributions paid to Altus Preferred Unit limited partners(11)— — — — — — — — 
Distributions payable to Altus Preferred Unit limited partners(11)— — — — — — — — 
Distributions to noncontrolling interest - Egypt— — — — — — — (40)(40)
Common dividends declared ($0.025 per share)
— — (9)— — — (9)— (9)
Other— — 1 — — 1 2 — 2 
Balance at March 31, 2021
$605 $262 $11,727 $(10,073)$(3,189)$15 $(1,258)$997 $(261)
For the Quarter Ended March 31, 2022
Balance at December 31, 2021$712 $262 $11,645 $(9,488)$(4,036)$22 $(1,595)$878 $(717)
Net income attributable to common stock— — — 1,883 — — 1,883 — 1,883 
Net income attributable to noncontrolling interest - Egypt— — — — — — — 119 119 
Net income attributable to noncontrolling interest - Altus— — — — — — — 14 14 
Net loss attributable to Altus Preferred Unit limited partners(70)— — — — — — — — 
Distributions to noncontrolling interest - Egypt— — — — — — — (69)(69)
Common dividends declared ($0.125 per share)
— — (43)— — — (43)— (43)
Treasury stock activity, net— — — — (260)— (260)— (260)
Deconsolidation of Altus(642)— — — — — — (72)(72)
Other— — (2)— — (1)(3)— (3)
Balance at March 31, 2022
$ $262 $11,600 $(7,605)$(4,296)$21 $(18)$870 $852 
(1)    As a result of the BCP Business Combination, the Company deconsolidated Altus on February 22, 2022. Refer to Note 1—Summary of Significant Accounting Policies and Note 2—Acquisitions and Divestitures for further detail.

The accompanying notes to consolidated financial statements are an integral part of this statement.
5


APA CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
These consolidated financial statements have been prepared by APA Corporation (APA 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 any recently adopted accounting pronouncements. 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 condensed or 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 the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2021, which contains a summary of the Company’s significant accounting policies and other disclosures.
On March 1, 2021, Apache Corporation, the Company’s predecessor registrant, consummated a holding company reorganization (the Holding Company Reorganization), pursuant to which Apache Corporation became a direct, wholly owned subsidiary of APA Corporation, and all of Apache Corporation’s outstanding shares automatically converted into equivalent corresponding shares of APA. Pursuant to the Holding Company Reorganization, APA became the successor issuer to Apache Corporation pursuant to Rule 12g-3(a) under the Exchange Act and replaced Apache Corporation as the public company trading on the Nasdaq Global Select Market under the ticker symbol “APA.” The Holding Company Reorganization modernized the Company’s operating and legal structure to more closely align with its growing international presence, making it more consistent with other companies that have subsidiaries operating around the globe.
1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
As of March 31, 2022, the Company's significant accounting policies are consistent with those discussed in Note 1—Summary of Significant Accounting Policies of the Notes to Consolidated Financial Statements contained in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2021. The Company’s financial statements for prior periods include reclassifications that were made to conform to the current-year presentation, if applicable.
Principles of Consolidation
The accompanying consolidated financial statements include the accounts of APA and its subsidiaries after elimination of intercompany balances and transactions.
The implementation of the Holding Company Reorganization was accounted for as a merger under common control. APA recognized the assets and liabilities of Apache at carryover basis. The consolidated financial statements of APA present comparative information for prior years on a combined basis, as if both APA and Apache were under common control for all periods presented.
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, it 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 subsidiary of APA 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 the Company’s consolidated Egypt oil and gas business as a noncontrolling interest, which is reflected as a separate noncontrolling interest component of equity in the Company’s consolidated balance sheet. Additionally, prior to the BCP Business Combination defined below, third-party investors owned a minority interest of approximately 21 percent of Altus Midstream Company (ALTM or Altus), which was reflected as a separate noncontrolling interest component of equity in the Company’s consolidated balance sheet. ALTM qualified as a variable interest entity under GAAP, which APA consolidated because a wholly owned subsidiary of APA had a controlling financial interest and was determined to be the primary beneficiary. Additionally, the assets of ALTM could only be used to settle obligations of ALTM. There was no recourse to the Company for ALTM’s liabilities.
6


On February 22, 2022, ALTM closed a previously announced transaction to combine with privately owned BCP Raptor Holdco LP (BCP and, together with BCP Raptor Holdco GP, LLC, the Contributed Entities) in an all-stock transaction, pursuant to the Contribution Agreement entered into by and among ALTM, Altus Midstream LP, New BCP Raptor Holdco, LLC (the Contributor), and BCP (the BCP Contribution Agreement). Pursuant to the BCP Contribution Agreement, the Contributor contributed all of the equity interests of the Contributed Entities (the Contributed Interests) to Altus Midstream LP, with each Contributed Entity becoming a wholly owned subsidiary of Altus Midstream LP (the BCP Business Combination). Upon closing the transaction, the combined entity was renamed Kinetik Holdings Inc. (Kinetik), and the Company determined that it was no longer the primary beneficiary of ALTM. The Company further determined that ALTM no longer qualified as a variable interest entity under GAAP. As a result, the Company deconsolidated ALTM on February 22, 2022. Refer to Note 2—Acquisitions and Divestitures for further detail.
The stockholders agreement entered into by and among the Company, ALTM, BCP, and other related and affiliated entities provides that the Company, through one of its wholly owned subsidiaries, retains the ability to designate a director to the board of directors of Kinetik for so long as the Company and its affiliates beneficially own 10 percent or more of Kinetik’s outstanding common stock. Based on this board representation, combined with the Company’s stock ownership, management determined it has significant influence over Kinetik. Investments in which the Company has significant influence, but not control, are accounted for under the equity method of accounting. These investments are recorded separately as “Equity method interests” in the Company’s consolidated balance sheet. The Company elected the fair value option to account for its equity method interest in Kinetik. Refer to Note 6—Equity Method Interests for further detail.
Use of Estimates
Preparation of financial statements in conformity with GAAP and disclosure of contingent assets and liabilities requires management to make estimates and assumptions that affect 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. The Company bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. The Company evaluates its estimates and assumptions on a regular basis. Actual results may differ from these estimates and assumptions used in preparation of the Company’s financial statements, and changes in these estimates are recorded when known.
Significant estimates with regard to these financial statements include the estimates of fair value for long-lived assets (refer to “Fair Value Measurements” and “Property and Equipment” sections in this Note 1 below), the fair value determination of acquired assets and liabilities (refer to Note 2—Acquisitions and Divestitures), the fair value of equity method interests (refer to “Equity Method Interests” within this Note 1 below and Note 6—Equity Method Interests), the assessment of asset retirement obligations (refer to Note 8—Asset Retirement Obligation), the estimation of the contingent liability representing Apache’s potential obligation to decommission sold properties in the Gulf of Mexico (refer to Note 11—Commitments and Contingencies), the estimate of income taxes (refer to Note 10—Income Taxes), and the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom.
Fair Value Measurements
Certain assets and liabilities are reported at fair value on a recurring basis in the Company’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).
Refer to Note 4—Derivative Instruments and Hedging Activities, Note 6Equity Method Interests, Note 9—Debt and Financing Costs, and Note 12—Redeemable Noncontrolling Interest - Altus for further detail regarding the Company’s fair value measurements recorded on a recurring basis.
7


During the quarters ended March 31, 2022 and 2021, the Company recorded no asset impairments in connection with fair value assessments.
Revenue Recognition
There have been no significant changes to the Company’s contracts with customers during the three months ended March 31, 2022 and 2021.
Payments under all contracts with customers are typically due and received within a short-term period of one year or less after physical delivery of the product or service has been rendered. Receivables from contracts with customers, net of allowance for credit losses, were $1.5 billion and $956 million as of March 31, 2022 and December 31, 2021, respectively. Refer to Note 14—Business Segment Information for a disaggregation of oil, gas, and natural gas production revenue by product and reporting segment.
Oil and gas production revenues from non-customers represent income taxes paid to the Arab Republic of Egypt by Egyptian General Petroleum Corporation on behalf of the Company. Revenue and associated expenses related to such tax volumes are recorded as “Oil, natural gas, and natural gas liquids production revenues” and “Current income tax provision,” respectively, in the Company’s statement of consolidated operations. Refer to Note 14—Business Segment Information for a disaggregation of revenue by product and reporting segment.
In accordance with the provisions of ASC 606, “Revenue from Contracts with Customers,” variable market prices for each short-term commodity sale are allocated entirely to each performance obligation as the terms of payment relate specifically to the Company’s efforts to satisfy its obligations. As such, the Company has elected the practical expedients available under the standard to not disclose the aggregate transaction price allocated to unsatisfied, or partially unsatisfied, performance obligations as of the end of the reporting period.
Property and Equipment
The carrying value of the Company’s property and equipment represents the cost incurred to acquire the property and equipment, including capitalized interest, net of any impairments. For business combinations, property and equipment cost is based on the fair values at the acquisition date.
Oil and Gas Property
The Company follows the successful efforts method of accounting for its oil and gas property. Under this method of accounting, exploration costs, such as exploratory 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.
8


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 the Company’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. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments, a Level 3 fair value measurement.
Unproved leasehold impairments are typically recorded as a component of “Exploration” expense in the Company’s statement of consolidated operations. Gains and losses on divestitures of the Company’s oil and gas properties are recognized in the statement of consolidated operations upon closing of the transaction. Refer to Note 2—Acquisitions and Divestitures for more detail.
Gathering, Processing, and Transmission Facilities
GPT facilities are depreciated on a straight-line basis over the estimated useful lives of the assets. The estimation of useful life takes into consideration anticipated production lives from the fields serviced by the GPT assets, whether APA-operated or third party-operated, as well as potential development plans by the Company for undeveloped acreage within, or close to, those fields.
The Company assesses the carrying amount of its GPT facilities whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. If the carrying amount of these facilities is more than the sum of the undiscounted cash flows, an impairment loss is recognized for the excess of the carrying value over its fair value.
2.    ACQUISITIONS AND DIVESTITURES
2022 Activity
The BCP Business Combination was completed on February 22, 2022. As consideration for the contribution of the Contributed Interests, ALTM issued 50 million shares of Class C Common Stock (and Altus Midstream LP issued a corresponding number of common units) to BCP’s unitholders, which are principally funds affiliated with Blackstone and I Squared Capital. ALTM’s stockholders continued to hold their existing shares of Common Stock. As a result of the transaction, the Contributor, or its designees, collectively owned approximately 75 percent of the issued and outstanding shares of ALTM Common Stock. Apache Midstream LLC, a wholly owned subsidiary of APA, which owned approximately 79 percent of the issued and outstanding shares of ALTM Common Stock prior to the BCP Business Combination, owned approximately 20 percent of the issued and outstanding shares of ALTM Common Stock after the transaction closed.

9


As a result of the BCP Business Combination, the Company deconsolidated ALTM on February 22, 2022 and recognized a gain of approximately $609 million that reflects the difference of the Company’s share of ALTM’s deconsolidated balance sheet and the fair value of its approximate 20 percent retained ownership in the combined entity. A summary of components of the gain, including the ALTM balance sheet amounts deconsolidated at the time of close, is included below:
As of February 22, 2022
(In millions)
Fair value of Kinetik Class A Common Stock held by Company$802 
ASSETS:
Cash and cash equivalents$143 
Other current assets29 
Property and equipment, net184 
Equity method interests1,367 
Other noncurrent assets12 
    Total assets deconsolidated$1,735 
LIABILITIES:
Current liabilities$3 
Long-term debt657 
Other noncurrent liabilities168 
Total liabilities deconsolidated$828 
NONCONTROLLING INTERESTS:
Redeemable noncontrolling interest preferred unit limited partners$642 
Noncontrolling interest-Altus72 
Total noncontrolling interests deconsolidated$714 
Net effect of deconsolidating balance sheet$(193)
Gain on deconsolidation of ALTM$609 
In March 2022, the Company sold four million of its shares in Kinetik for cash proceeds of $224 million and recognized a loss of $25 million, including transaction fees. Refer to Note 6—Equity Method Interests for further detail. In connection with this secondary offering, the Company has agreed that within the next 24 months, it will invest a minimum of $100 million of these proceeds for new well drilling and completion activity at the Alpine High play in the Delaware Basin, where Kinetik has exclusive gas and NGL gathering and processing rights.
In March 2022, the Company completed the previously announced transaction to sell certain non-core mineral rights in the Delaware Basin for total cash proceeds of approximately $759 million after certain post-closing adjustments. The Company recognized a gain of approximately $590 million from the transaction. The Company also completed the sale of other non-core assets and leasehold in multiple transactions for total cash proceeds of $8 million. The Company recognized a gain of approximately $2 million upon closing of these transactions during the first quarter of 2022.
10


2021 Activity
During the first quarter of 2021, the Company completed leasehold and property acquisitions, primarily in the Permian Basin, for total cash consideration of $2 million. The Company also completed the sale of certain non-core assets and leasehold, primarily in the Permian Basin, in multiple transactions for total cash proceeds of $3 million. The Company recognized a gain of approximately $2 million upon closing of these transactions during the first quarter of 2021.
3.    CAPITALIZED EXPLORATORY WELL COSTS
The Company’s capitalized exploratory well costs were $389 million and $321 million as of March 31, 2022 and December 31, 2021, respectively. The increase is primarily attributable to additional drilling activity in Suriname and Egypt.
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 on the majority of its worldwide production, as well as fluctuations in exchange rates in connection with transactions denominated in foreign currencies. The Company manages the variability in its cash flows by occasionally entering into derivative transactions on a portion of its crude oil and natural gas production and foreign currency transactions. The Company utilizes various types of derivative financial instruments, including forward contracts, futures contracts, swaps, and options, to manage fluctuations in cash flows resulting from changes in commodity prices or foreign currency values.
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, the Company utilizes a diversified group of investment-grade rated counterparties, primarily financial institutions, for its derivative transactions. As of March 31, 2022, the Company had derivative positions with 12 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, the Company may not realize the benefit of some of its derivative instruments resulting from lower commodity prices or changes in currency exchange rates.
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Derivative Instruments
Commodity Derivative Instruments
As of March 31, 2022, the Company had the following open natural gas financial basis swap contracts:
Basis Swap PurchasedBasis Swap Sold
Production PeriodSettlement IndexMMBtu
(in 000’s)
Weighted Average Price DifferentialMMBtu
(in 000’s)
Weighted Average Price Differential
January—December 2022NYMEX Henry Hub/IF Waha33,000 $(0.45)— 
January—December 2022NYMEX Henry Hub/IF HSC— 33,000 $(0.08)
July—December 2022NYMEX Henry Hub/IF Waha20,240 $(0.97)— 
July—December 2022NYMEX Henry Hub/IF HSC— 20,240 $(0.17)
October—December 2022NYMEX Henry Hub/IF Waha920 $(1.19)— 
October—December 2022NYMEX Henry Hub/IF HSC— 920 $(0.19)
January—March 2023NYMEX Henry Hub/IF Waha3,150 $(1.06)— 
January—March 2023NYMEX Henry Hub/IF HSC— 3,150 $(0.03)
January—June 2023NYMEX Henry Hub/IF Waha4,525 $(1.54)— 
January—June 2023NYMEX Henry Hub/IF HSC— 4,525 $(0.11)
January—December 2023NYMEX Henry Hub/IF Waha73,000 $(1.15)— 
January—December 2023NYMEX Henry Hub/IF HSC— 73,000 $(0.08)
Subsequent to March 31, 2022, the Company entered into basis swap contracts purchasing Nymex Henry Hub/Waha totaling 1,840,000 MMBtu with a weighted average strike price of $(1.62) and selling Nymex Henry Hub/HSC totaling 1,840,000 MMBtu with a weighted average strike price of $(0.19) for July to September 2023.
Foreign Currency Derivative Instruments
The Company has open foreign currency costless collar contracts in GBP/USD for £15 million per month for the calendar year 2022 with a weighted average floor and ceiling price of $1.39 and $1.29, respectively.
Embedded Derivatives
Altus Preferred Units Embedded Derivative
The Altus Preferred Units embedded derivative was deconsolidated as of March 31, 2022 as part of the BCP Business Combination. Refer to Note 2Acquisitions and Divestitures for discussion of the BCP Business Combination and Note 12—Redeemable Noncontrolling Interest - Altus for a description of the Altus Preferred Units and associated embedded derivative.
Pipeline Capacity Embedded Derivatives
During the fourth quarter of 2019 and first quarter of 2020, the Company entered into agreements to assign a portion of its contracted capacity under an existing transportation agreement to third parties. Embedded in these agreements were arrangements under which the Company received payments calculated based on pricing differentials between Houston Ship Channel and Waha during the calendar years 2020 and 2021. This feature required bifurcation and measurement of the change in market value throughout 2020 and 2021. Unrealized gains and losses in the fair value of this feature were recorded as “Derivative instrument gains (losses), net” under “Revenues and Other” in the statement of consolidated operations, and the balance at the end of December 31, 2021 will be amortized into income over the original tenure of the host contract.
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Fair Value Measurements
The following table presents the Company’s derivative assets and liabilities measured at fair value on a recurring basis:
Fair Value Measurements Using
Quoted Price in Active Markets
(Level 1)
Significant Other Inputs
(Level 2)
Significant Unobservable Inputs
(Level 3)
Total
Fair Value
Netting(1)
Carrying Amount
(In millions)
March 31, 2022
Assets:
Commodity derivative instruments$ $ $ $ $5 $5 
Liabilities:
Commodity derivative instruments 34  34 5 39 
Foreign currency derivative instruments 2  2  2 
December 31, 2021
Liabilities:
Commodity derivative instruments$ $10 $ $10 $ $10 
Pipeline capacity embedded derivative 46  46  46 
Preferred Units embedded derivative  57 57  57 
(1)    The derivative fair values are based on analysis of each contract on a gross basis, excluding the impact of netting agreements with counterparties.
The fair values of the Company’s derivative instruments are not actively quoted in the open market. The Company primarily uses a market approach to estimate the fair values of these derivatives on a recurring basis, utilizing futures pricing for the underlying positions provided by a reputable third party, a Level 2 fair value measurement.
Derivative Activity Recorded in the Consolidated Balance Sheet
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,
2022
December 31,
2021
(In millions)
Current Assets: Other current assets$4 $ 
Other Assets: Deferred charges and other1  
Total derivative assets$5 $ 
Current Liabilities: Other current liabilities$20 $4 
Deferred Credits and Other Noncurrent Liabilities: Other21 109 
Total derivative liabilities$41 $113 
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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,
20222021
 (In millions)
Realized:
Commodity derivative instruments$(5)$148 
Realized gain (loss), net(5)148 
Unrealized:
Commodity derivative instruments(24)26 
Pipeline capacity embedded derivatives 1 
Foreign currency derivative instruments(2) 
Preferred Units embedded derivative(31)(17)
Unrealized gain (loss), net(57)10 
Derivative instrument gains (losses), net$(62)$158 
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 (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 losses (gains), net” in “Adjustments to reconcile net income (loss) to net cash provided by operating activities.”
The Company seeks to maintain a balance between “first of month” and “gas daily pricing” for its U.S. natural gas portfolio and sales activities in a given month as part of its ordinary course of business. This is typically implemented through a combination of physical and financial contracts that settle monthly. In January 2021, the Company entered into financial contracts that increased its exposure to “gas daily pricing” and reduced its exposure to “first of month” pricing for February 2021. The Company realized a gain of $147 million in connection with these contracts in the first quarter of 2021 as a result of extreme daily gas price volatility across Texas in February resulting from Winter Storm Uri.
5.    OTHER CURRENT ASSETS
The following table provides detail of the Company’s other current assets:
March 31,
2022
December 31,
2021
 (In millions)
Inventories$529 $473 
Drilling advances