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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 June 30, 2024
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.)
2000 W. Sam Houston Pkwy. S., Suite 200, Houston, Texas 77042-3643
(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 July 31, 2024
369,904,843 




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, plans and objectives of management for future operations and capital returns framework, the anticipated benefits of the merger (the Callon acquisition) between the Company and Callon Petroleum Company (Callon), the anticipated impact of the Callon acquisition on the combined company’s business and future financial and operating results, and the anticipated financial and operational impact and timing of the expected synergies from the Callon acquisition, 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, 2023, 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,” “goal,” “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:
changes in local, regional, national, and international economic conditions, including as a result of any epidemics or pandemics, such as the coronavirus disease (COVID-19) pandemic and any related variants;
the market prices of oil, natural gas, natural gas liquids (NGLs), and other products or services, including the prices received for natural gas purchased from third parties to sell and deliver to a U.S. LNG export facility;
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 armed conflict in Israel and Gaza, and actions taken by foreign oil and gas producing nations, including the Organization of the Petroleum Exporting Countries (OPEC) and non-OPEC members that participate in OPEC initiatives (OPEC+);
the availability of capital resources;
capital expenditures and other contractual obligations;
currency exchange rates;
weather conditions;
inflation rates;
the impact of changes in tax legislation;
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;
cyberattacks and terrorism;
the Company’s ability to access the capital markets;
market-related risks, such as general credit, liquidity, and interest-rate risks;
the ability to retain and hire key personnel;
property acquisitions or divestitures;



the integration of acquisitions, including the diversion of management time on integration-related issues for the Callon acquisition and the risk that the Company may not integrate Callon’s operations in a successful manner or in the expected time period;
the risk that the anticipated benefits, cost savings, synergies, and growth from the Callon acquisition may not be fully realized or may take longer to realize than expected;
negative effects of the Callon acquisition on the Company’s business relationships and business generally, the market price of the Company’s common stock, and/or the Company’s operating results;
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, 2023;
other risks and uncertainties disclosed in the Company’s second-quarter 2024 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:
“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
June 30,
For the Six Months Ended
June 30,
2024202320242023
 (In millions, except share data)
REVENUES AND OTHER:
Oil, natural gas, and natural gas liquids production revenues(1)
$2,201 $1,652 $3,949 $3,421 
Purchased oil and gas sales(1)
342 144 545 383 
Total revenues2,543 1,796 4,494 3,804 
Derivative instrument gains (losses), net(3)51 (7)104 
Gain on divestitures, net276 5 283 6 
Loss on previously sold Gulf of Mexico properties(17) (83) 
Other, net(7)109 8 77 
2,792 1,961 4,695 3,991 
OPERATING EXPENSES:
Lease operating expenses(1)
460 361 798 682 
Gathering, processing, and transmission(1)
121 78 205 156 
Purchased oil and gas costs(1)
210 131 373 347 
Taxes other than income78 50 135 102 
Exploration71 43 219 95 
General and administrative85 72 178 137 
Transaction, reorganization, and separation115 2 142 6 
Depreciation, depletion, and amortization588 367 1,018 699 
Asset retirement obligation accretion36 29 76 57 
Impairments 46  46 
Financing costs, net100 82 176 154 
1,864 1,261 3,320 2,481 
NET INCOME BEFORE INCOME TAXES928 700 1,375 1,510 
Current income tax provision285 254 585 600 
Deferred income tax provision (benefit)23 (16)(42)122 
NET INCOME INCLUDING NONCONTROLLING INTERESTS620 462 832 788 
Net income attributable to noncontrolling interest
79 81 159 165 
NET INCOME ATTRIBUTABLE TO COMMON STOCK$541 $381 $673 $623 
NET INCOME PER COMMON SHARE:
Basic$1.46 $1.24 $2.00 $2.01 
Diluted$1.46 $1.23 $2.00 $2.01 
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic371 308 337 310 
Diluted372 309 337 310 
(1)    For transactions with Kinetik prior to the Company’s sale of its remaining shares of Kinetik Class A Common Stock and the resignation of the Company’s designated director from the Kinetik board of directors, refer to Note 6—Equity Method Interests.
The accompanying notes to consolidated financial statements are an integral part of this statement.
1


APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME
(Unaudited)
 
For the Quarter Ended
June 30,
For the Six Months Ended
June 30,
 2024202320242023
 (In millions)
NET INCOME INCLUDING NONCONTROLLING INTERESTS$620 $462 $832 $788 
OTHER COMPREHENSIVE INCOME, NET OF TAX:
Pension and postretirement benefit plan(1) (1)3 
COMPREHENSIVE INCOME INCLUDING NONCONTROLLING INTERESTS619 462 831 791 
Comprehensive income attributable to noncontrolling interest
79 81 159 165 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON STOCK$540 $381 $672 $626 

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 Six Months Ended
June 30,
  20242023
 (In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income including noncontrolling interests$832 $788 
Adjustments to reconcile net income to net cash provided by operating activities:
Unrealized derivative instrument (gains) losses, net5 (80)
Gain on divestitures, net(283)(6)
Exploratory dry hole expense and unproved leasehold impairments174 64 
Depreciation, depletion, and amortization1,018 699 
Asset retirement obligation accretion76 57 
Impairments 46 
Provision for (benefit from) deferred income taxes
(42)122 
Gain on extinguishment of debt
 (9)
Loss on previously sold Gulf of Mexico properties83  
Other, net31 (67)
Changes in operating assets and liabilities:
Receivables(101)100 
Inventories(2)(45)
Drilling advances and other current assets6 2 
Deferred charges and other long-term assets80 160 
Accounts payable(125)(112)
Accrued expenses(312)(163)
Deferred credits and noncurrent liabilities(195)(221)
NET CASH PROVIDED BY OPERATING ACTIVITIES1,245 1,335 
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to upstream oil and gas property(1,223)(1,119)
Leasehold and property acquisitions(63)(10)
Proceeds from asset divestitures729 28 
Proceeds from sale of Kinetik Shares
428  
Other, net(23)(14)
NET CASH USED IN INVESTING ACTIVITIES(152)(1,115)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from commercial paper and revolving credit facilities, net
63 196 
Proceeds from term loan facility
1,500  
Payment on Callon Credit Agreement
(472) 
Payments on fixed-rate debt
(1,641)(65)
Distributions to noncontrolling interest
(123)(100)
Treasury stock activity, net(144)(188)
Dividends paid to APA common stockholders(168)(155)
Other, net(35)(11)
NET CASH USED IN FINANCING ACTIVITIES(1,020)(323)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS73 (103)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR87 245 
CASH AND CASH EQUIVALENTS AT END OF PERIOD$160 $142 
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest$178 $168 
Income taxes paid, net of refunds566 476 
The accompanying notes to consolidated financial statements are an integral part of this statement.
3


APA CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
June 30,
2024
December 31,
2023
(In millions, except share data)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents$160 $87 
Receivables, net of allowance of $122 and $114
1,936 1,610 
Other current assets (Note 5)
822 765 
2,918 2,462 
PROPERTY AND EQUIPMENT:
Oil and gas properties49,416 44,860 
Gathering, processing, and transmission facilities445 448 
Other539 634 
Less: Accumulated depreciation, depletion, and amortization(35,944)(35,904)
14,456 10,038 
OTHER ASSETS:
Equity method interests (Note 6)
 437 
Decommissioning security for sold Gulf of Mexico properties (Note 11)
21 21 
Deferred tax asset (Note 10)
2,259 1,758 
Deferred charges and other541 528 
$20,195 $15,244 
LIABILITIES, NONCONTROLLING INTERESTS, AND EQUITY
CURRENT LIABILITIES:
Accounts payable$1,012 $658 
Current debt2 2 
Other current liabilities (Note 7)
1,875 1,744 
2,889 2,404 
LONG-TERM DEBT (Note 9)
6,741 5,186 
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Deferred tax liability (Note 10)
256 371 
Asset retirement obligation (Note 8)
2,515 2,362 
Decommissioning contingency for sold Gulf of Mexico properties (Note 11)
768 764 
Other531 466 
4,070 3,963 
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 491,336,993 and 420,595,901 shares issued, respectively
307 263 
Paid-in capital13,322 11,126 
Accumulated deficit(2,286)(2,959)
Treasury stock, at cost, 121,511,189 and 117,020,000 shares, respectively
(5,934)(5,790)
Accumulated other comprehensive income14 15 
APA SHAREHOLDERS’ EQUITY5,423 2,655 
Noncontrolling interest
1,072 1,036 
TOTAL EQUITY6,495 3,691 
$20,195 $15,244 


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 AND NONCONTROLLING INTERESTS
(Unaudited)
Common
Stock
Paid-In
Capital
Accumulated DeficitTreasury
Stock
Accumulated
Other
Comprehensive
Income
APA SHAREHOLDERS’
EQUITY
Noncontrolling
Interest
TOTAL
EQUITY
(In millions)
For the Quarter Ended June 30, 2023
Balance at March 31, 2023
$263 $11,337 $(5,572)$(5,601)$17 $444 $989 $1,433 
Net income attributable to common stock— — 381 — — 381 — 381 
Net income attributable to noncontrolling interest
— — — — — — 81 81 
Distributions to noncontrolling interest
— — — — — — (83)(83)
Common dividends declared ($0.25 per share)
— (77)— — — (77)— (77)
Treasury stock activity, net— — — (46)— (46)— (46)
Other— 7 — — — 7 — 7 
Balance at June 30, 2023
$263 $11,267 $(5,191)$(5,647)$17 $709 $987 $1,696 
For the Quarter Ended June 30, 2024
Balance at March 31, 2024
$263 $11,047 $(2,827)$(5,891)$15 $2,607 $1,046 $3,653 
Net income attributable to common stock— — 541 — — 541 — 541 
Net income attributable to noncontrolling interest
— — — — — — 79 79 
Distributions to noncontrolling interest
— — — — — — (53)(53)
Common dividends declared ($0.25 per share)
— (93)— — — (93)— (93)
Issuance of common stock
44 2,370 — — — 2,414 — 2,414 
Treasury stock activity, net— — — (43)— (43)— (43)
Other— (2)— — (1)(3)— (3)
Balance at June 30, 2024
$307 $13,322 $(2,286)$(5,934)$14 $5,423 $1,072 $6,495 


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


APA CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CHANGES IN EQUITY AND NONCONTROLLING INTERESTS - Continued
(Unaudited)
Common
Stock
Paid-In
Capital
Accumulated DeficitTreasury
Stock
Accumulated
Other
Comprehensive
Income
APA
SHAREHOLDERS’
EQUITY
Noncontrolling
Interest
TOTAL EQUITY
For the Six Months Ended June 30, 2023
Balance at December 31, 2022
$262 $11,420 $(5,814)$(5,459)$14 $423 $922 $1,345 
Net income attributable to common stock623 — — 623 — 623 
Net income attributable to noncontrolling interest – Egypt— — — — — — 165 165 
Distributions to noncontrolling interest – Egypt— — — — — — (100)(100)
Common dividends declared ($0.50 per share)
— (155)— — — (155)— (155)
Treasury stock activity, net— — — (188)— (188)— (188)
Other1 2 — — 3 6 — 6 
Balance at June 30, 2023
$263 $11,267 $(5,191)$(5,647)$17 $709 $987 $1,696 
For the Six Months Ended June 30, 2024
Balance at December 31, 2023
$263 $11,126 $(2,959)$(5,790)$15 $2,655 $1,036 $3,691 
Net income attributable to common stock— — 673 — — 673 — 673 
Net income attributable to noncontrolling interest – Egypt— — — — — — 159 159 
Distributions to noncontrolling interest – Egypt— — — — — — (123)(123)
Common dividends declared ($0.50 per share)
— (168)— — — (168)— (168)
Issuance of common stock
44 2,370 — — — 2,414 — 2,414 
Treasury stock activity, net— — — (144)— (144)— (144)
Other (6)— — (1)(7)— (7)
Balance at June 30, 2024
$307 $13,322 $(2,286)$(5,934)$14 $5,423 $1,072 $6,495 


The accompanying notes to consolidated financial statements are an integral part of this statement.
6


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, 2023, which contains a summary of the Company’s significant accounting policies and other disclosures.
1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
As of June 30, 2024, 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, 2023. The Company’s financial statements for prior periods may include reclassifications that were made to conform to the current-year presentation.
Principles of Consolidation
The accompanying consolidated financial statements include the accounts of APA 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, it has more than a 50 percent voting interest or controls the financial and operating decisions.
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. The Company has determined that a limited partnership and APA subsidiary, which has control over APA’s Egyptian operations, qualifies as a variable interest entity (VIE) under GAAP. Apache consolidates the activities of APA’s Egyptian operations because it has concluded that a wholly owned subsidiary has a controlling financial interest in APA’s Egyptian operations and was determined to be the primary beneficiary of the VIE.
Investments in which the Company has significant influence, but not control, are accounted for under the equity method of accounting. During each of the periods ended March 31, 2024 and June 30, 2023, the Company had a designated director on the Kinetik Holdings Inc. (Kinetik) board of directors. The Company’s designated director resigned from the Kinetik board of directors on April 3, 2024. As a result, the Company is considered to have had significant influence over Kinetik for all periods presented except for the quarter ended June 30, 2024.
As of December 31, 2023, the Company held shares of Kinetik Class A Common Stock (Kinetik Shares), which were recorded separately as “Equity method interests” in the Company’s consolidated balance sheet. On March 18, 2024, the Company sold its remaining Kinetik Shares. Refer to Note 6—Equity Method Interests for further detail.

7


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 assessment of asset retirement obligations (refer to Note 8—Asset Retirement Obligation), the estimate of income taxes (refer to Note 10—Income Taxes), the estimation of the contingent liability representing Apache’s potential decommissioning obligations on sold properties in the Gulf of Mexico (refer to Note 11—Commitments and Contingencies), 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 6—Equity Method Interests, and Note 9—Debt and Financing Costs for further detail regarding the Company’s fair value measurements recorded on a recurring basis.
During the three and six months ended June 30, 2024 and 2023, the Company recorded no asset impairments in connection with fair value assessments.
Revenue Recognition
Receivables from contracts with customers, including receivables for purchased oil and gas sales and net of allowance for credit losses, were $1.8 billion and $1.5 billion as of June 30, 2024 and December 31, 2023, respectively. 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. Over the past year, the Company experienced a gradual decline in the timeliness of receipts from the Egyptian General Petroleum Corporation (EGPC) for the Company’s Egyptian oil and gas sales. The Company is conducting ongoing discussions with the Government of Egypt to resolve the delay in EGPC payments. The Company continues to collect on these receivables, albeit late, and management believes that the Company will be able to collect the total balance of its receivables from this customer.
Oil and gas production revenues include income taxes that will be paid to the Arab Republic of Egypt by EGPC 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 13—Business Segment Information for a disaggregation of oil, gas, and natural gas production revenue by product and reporting segment.
8


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.
Inventories
Inventories consist principally of tubular goods and equipment and are stated at the lower of weighted-average cost or net realizable value. Oil produced but not sold, primarily in the North Sea, is also recorded to inventory and is stated at the lower of the cost to produce or net realizable value.
During the three and six months ended June 30, 2023, the Company recorded $46 million of impairments in connection with valuations of drilling and operations equipment inventory upon the Company’s decision to suspend drilling operations in the North Sea. There were no impairments recorded during the three and six months ended June 30, 2024.
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 and acquisitions, 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, production costs, 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. At the end of each quarter, management reviews the status of all suspended exploratory well costs in light of ongoing exploration activities, and if management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed.
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.
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.
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 (GPT) 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.
9


Transaction, Reorganization, and Separation (TRS)
The Company recorded $115 million and $142 million of TRS costs during the second quarter and the first six months of 2024, respectively, and $2 million and $6 million of TRS costs during the second quarter and the first six months of 2023, respectively. TRS costs incurred in the first six months of 2024 comprised $128 million associated with the Callon acquisition, including $62 million of separation costs and $66 million of transaction and integration costs.
New Pronouncements Issued But Not Yet Adopted
There were no material changes in recently issued or adopted accounting standards from those disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2023.
2.    ACQUISITIONS AND DIVESTITURES
2024 Activity
Callon Petroleum Company Acquisition
On April 1, 2024, APA completed its acquisition of Callon Petroleum Company (Callon) in an all-stock transaction valued at approximately $4.5 billion, inclusive of Callon’s debt (the Callon acquisition). The transaction was approved by APA and Callon shareholders at special meetings held on March 27, 2024. The acquired assets include approximately 120,000 net acres in the Delaware Basin and 25,000 net acres in the Midland Basin.

Subject to the terms of the merger agreement (Merger Agreement), each share of Callon common stock was converted into the right to receive 1.0425 shares of APA common stock, with cash in lieu of fractional shares. As a result, APA issued approximately 70 million shares of APA common stock in connection with the transaction based on the value of APA common stock on the day of closing, and following the acquisition, Callon common stock is no longer listed for trading on the NYSE. In addition to the equity consideration provided, APA transferred approximately $24 million in other consideration upon close of the transaction.
Upon completing the acquisition, APA repaid all of Callon’s debt, refinancing a portion by borrowing $1.5 billion under its unsecured committed term loan facility. Refer to Note 9—Debt and Financing Costs for further detail.
Recording of Assets Acquired and Liabilities Assumed
The transaction was accounted for using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date. The final determination of fair value for certain assets and liabilities will be completed as soon as the information necessary to complete the analysis is obtained. These amounts will be finalized as soon as possible, but no later than one year from the acquisition date.
The following table summarizes the preliminary estimates of the assets acquired and liabilities assumed in the merger:
(In millions)
Current assets
$282 
Property, plant, and equipment
4,493 
Deferred tax asset
575 
Other assets11 
Total assets acquired$5,361 
Current liabilities$616 
Long-term debt
2,113 
Asset retirement obligation136 
Other long-term obligations58 
Total liabilities assumed$2,923 
Net assets acquired$2,438 
10


The following unaudited pro forma combined results for the three and six months ended June 30, 2024 and 2023 reflect the consolidated results of operations of the Company as if the Callon acquisition had occurred on January 1, 2023. The unaudited pro forma information includes certain accounting adjustments for transaction costs, depreciation, depletion, and amortization expense, and estimated tax impacts of the pro forma adjustments.
For the Quarter Ended
June 30,
For the Six Months Ended
June 30,
2024202320242023
(In millions, except share data)
Revenues
$2,201 $2,337 $4,513 $4,883 
Net income attributable to common stock
630 508 779 790 
Net income per common share – basic
1.70 1.35 2.10 2.08 
Net income per common share – diluted
1.69 1.34 2.10 2.08 
From the date of the acquisition through June 30, 2024, revenues and net income attributable to common stockholders associated with Callon assets totaled $438 million and $109 million, respectively.
The unaudited pro forma condensed consolidated financial information has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the transactions taken place on the dates indicated. The unaudited pro forma results are also not intended to be a projection of future results and do not include any future cost savings or other synergies that may result from the Callon acquisition or any estimated costs that have not yet been incurred.
U.S. Divestitures
In the second quarter of 2024, the Company completed the sale of non-core acreage in the East Texas Austin Chalk and Eagle Ford plays that had a carrying value of $347 million for aggregate cash proceeds of $253 million and the assumption of asset retirement obligations of $48 million. The Company recognized a $46 million loss during the second quarter of 2024 in association with this sale.
In the second quarter of 2024, the Company also completed the sale of non-core mineral and royalty interests in the Permian Basin that had a carrying value of $71 million for approximately $392 million after post-closing adjustments. The Company recognized a gain of $321 million during the second quarter of 2024 in association with this sale.
Additionally, during the second quarter and first six months of 2024, the Company completed the sale of non-core assets and leasehold in multiple transactions for aggregate cash proceeds of $45 million and $72 million, respectively, recognizing a gain of approximately $1 million and $8 million, respectively, upon closing of these transactions.
Sale of Kinetik Shares
On March 18, 2024, the Company sold its remaining Kinetik Shares for cash proceeds of $428 million. Refer to Note 6—Equity Method Interests for further detail.
Leasehold and Property Acquisitions
During the first six months of 2024, in addition to the Callon acquisition, the Company completed other leasehold and property acquisitions, primarily in the Permian Basin, for aggregate cash consideration of approximately $63 million.
2023 Activity
Leasehold and Property Acquisitions
During the second quarter and first six months of 2023, the Company completed leasehold and property acquisitions, primarily in the Permian Basin, for aggregate cash consideration of approximately $4 million and $10 million, respectively.
U.S. Divestitures
During the second quarter and first six months of 2023, the Company completed the sale of non-core assets and leasehold in multiple transactions for aggregate cash proceeds of $7 million and $28 million, respectively, recognizing a gain of approximately $5 million and $6 million, respectively, upon closing of these transactions.
11


3.    CAPITALIZED EXPLORATORY WELL COSTS
The Company’s capitalized exploratory well costs were $621 million and $586 million as of June 30, 2024 and December 31, 2023, respectively. The increase is primarily attributable to additional drilling activity in Egypt and in the U.S. No suspended exploratory well costs previously capitalized for greater than one year at December 31, 2023 were charged to dry hole expense during the second quarter of 2024. During the first quarter of 2024, approximately $51 million of suspended well costs previously capitalized for greater than one year at December 31, 2023 were charged to dry hole expense.
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. 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, the Company utilizes a diversified group of investment-grade rated counterparties, primarily financial institutions, for its derivative transactions. As of June 30, 2024, the Company had derivative positions with one counterparty. 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.
Derivative Instruments
Commodity Derivative Instruments
As of June 30, 2024, the Company had the following open natural gas financial collar contracts:
Production PeriodSettlement IndexMMBtu
(in 000’s)
Weighted Average Floor Price
Weighted Average Ceiling Price
July—December 2024
NYMEX Henry Hub
3,398$3.00$3.33
As of June 30, 2024, the Company had the following open natural gas financial basis swap contracts:
Basis Swap PurchasedBasis Swap Sold
Production PeriodSettlement IndexMMBtu
(in 000’s)
Weighted Average Price DifferentialMMBtu
(in 000’s)
Weighted Average Price Differential
July—December 2024
NYMEX Henry Hub/IF Waha3,680$(1.06)
July—December 2024
NYMEX Henry Hub/IF HSC7,360$(0.42)
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As of June 30, 2024, the Company had the following open NGL fixed swap contracts:
Production PeriodSettlement Index
MBbls
(in 000’s)
Weighted Average Price Differential
July—December 2024
OPIS IsoButane Mt Belvieu Non TET
12$33.18
July—December 2024
OPIS NButane Mt Belvieu Non TET
36$33.18
Embedded Derivatives
As a result of the Callon acquisition, the Company assumed an earn-out obligation from Callon, where the Company could be required to pay up to $50 million in the aggregate if the average daily settlement price of WTI crude oil exceeds $60.00 per barrel for the 2024 and 2025 calendar years. Additionally, in connection with the Callon acquisition, the Company assumed a contingent consideration arrangement. Whereby the Company could receive up to $45 million if the average daily settlement price of WTI crude oil for 2024 is at least $80.00 per barrel. If the average daily settlement price of WTI crude oil for 2024 is less than $80.00 per barrel but at least $75.00 per barrel, then the Company would receive $20 million.
The Company determined that the earn-out obligation and contingent consideration receipt were not clearly and closely related to the underlying agreements and therefore bifurcated these embedded features and recorded these derivatives at fair value. For further discussion of these derivatives, refer to “Fair Value Measurements” below.
Fair Value Measurements
The following table presents the Company’s derivative assets and liabilities measured at fair value on a recurring basis:
Fair Value Measurements Using
Quoted Price in Active Markets
(Level 1)
Significant Other Inputs
(Level 2)
Significant Unobservable Inputs
(Level 3)
Total
Fair Value
Netting(1)
Carrying Amount
(In millions)
June 30, 2024
Assets:
Commodity derivative instruments$ $2 $ $2 $(1)$1 
Contingent consideration arrangements
 25  25  25 
Liabilities:
Commodity derivative instruments$ $1 $ $1 $(1)$ 
Contingent consideration arrangements
 42  42  42 
December 31, 2023
Assets:
Commodity derivative instruments$ $6 $ $6 $ $6 
(1)    The derivative fair values are based on analysis of each contract on a gross basis, excluding the impact of netting agreements with counterparties.
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The embedded options within the earn-out obligation and contingent consideration arrangements discussed above are considered financial instruments under ASC 815. The Company uses a market approach to estimate the fair values of these derivatives on a recurring basis, utilizing an option pricing model method provided by a reputable third party. The valuation includes significant inputs such as forward oil price curves, time to expiration, and implied volatility. As these inputs are substantially observable for the full term of the contingent consideration arrangements, the inputs are considered a Level 2 fair value measurement. As of June 30, 2024, the estimated fair values of the earn-out obligation and contingent consideration receipt were $42 million and $25 million, respectively.
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:
June 30,
2024
December 31,
2023
(In millions)
Current Assets: Other current assets$26 $6 
Total derivative assets$26 $6 
Current Liabilities: Other current liabilities$24 $ 
Deferred Credit and Other Noncurrent Liabilities: Other
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Total derivative liabilities$42 $ 
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
June 30,
For the Six Months Ended
June 30,
2024202320242023
 (In millions)
Realized:
Commodity derivative instruments$(6)$4 $(2)$24 
Realized gains (losses), net
(6)4 (2)24 
Unrealized:
Commodity derivative instruments3 47 (5)80 
Unrealized gains (losses), net3 47 (5)80 
Derivative instrument gains (losses), net$(3)$51 $(7)$104 
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 (gains) losses, net” under “Adjustments to reconcile net income to net cash provided by operating activities.”
5.    OTHER CURRENT ASSETS
The following table provides detail of the Company’s other current assets:
June 30,
2024
December 31,
2023
 (In millions)
Inventories$466 $453 
Drilling advances110 88 
Prepaid assets and other80 46 
Current decommissioning security for sold Gulf of Mexico assets166 178 
Total Other current assets$822 $765 
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6.    EQUITY METHOD INTERESTS
As of December 31, 2023, the Company held 13.1 million Kinetik Shares, which were recorded at fair value of $437 million and reflected separately as “Equity method interests” in the Company’s consolidated balance sheet. The Company elected the fair value option for measuring its equity method interest in Kinetik based on practical expedience, variances in reporting timelines, and cost-benefit considerations. The fair value of the Company’s interest in Kinetik was determined using observable share prices on a major exchange, a Level 1 fair value measurement. On March 18, 2024, the Company sold its remaining Kinetik Shares for cash proceeds of $428 million.
Prior to the Company’s sale of its remaining Kinetik Shares and the resignation of the Company’s designated director from the Kinetik board of directors, the Company recorded changes in the fair value of its equity method interest in Kinetik totaling a loss of $9 million in the first quarter of 2024, and gains of $90 million and $71 million in the second quarter and the first six months of 2023, respectively. This loss and these gains were recorded as a component of “Revenues and Other” in the Company’s statement of consolidated operations.
The following table represents related party sales and costs associated with Kinetik prior to the Company’s sale of its remaining Kinetik Shares and the resignation of the Company’s designated director from the Kinetik board of directors:
For the Quarter Ended
June 30,
For the Six Months Ended
June 30,
2024202320242023
(In millions)
Natural gas and NGLs sales$ $29 $13 $43 
Purchased oil and gas sales 7 22 7 
$ $36 $35 $50 
Gathering, processing, and transmission costs$ $29 $23 $55 
Purchased oil and gas costs 26 23 28 
Lease operating expenses
  2  
$ $55 $48 $83 
7.    OTHER CURRENT LIABILITIES
The following table provides detail of the Company’s other current liabilities:
June 30,
2024
December 31,
2023
 (In millions)
Accrued operating expenses$209 $162 
Accrued exploration and development730 371 
Accrued compensation and benefits162 390 
Accrued interest93 93 
Accrued income taxes168 138 
Current asset retirement obligation75 76 
Current operating lease liability103 116 
Current decommissioning contingency for sold Gulf of Mexico properties94 60 
Other241 338 
Total Other current liabilities$1,875 $1,744 
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8.    ASSET RETIREMENT OBLIGATION
The following table describes changes to the Company’s asset retirement obligation (ARO) liability:
June 30,
2024
 (In millions)
Asset retirement obligation, December 31, 2023
$2,438 
Liabilities incurred4 
Liabilities acquired140 
Liabilities settled(21)
Liabilities divested(48)
Accretion expense76 
Revisions in estimated liabilities1 
Asset retirement obligation, June 30, 2024
2,590 
Less current portion(75)
Asset retirement obligation, long-term$2,515 
9.    DEBT AND FINANCING COSTS
The following table presents the carrying values of the Company’s debt:
June 30,
2024
December 31,
2023
(In millions)
Apache notes and debentures before unamortized discount and debt issuance costs(1)
$4,835 $4,835 
Term loan facility, commercial paper, and syndicated credit facilities(2)
1,935 372 
Apache finance lease obligations31 32 
Unamortized discount(26)(26)
Debt issuance costs(32)(25)
Total debt6,743 5,188 
Current maturities(2)(2)
Long-term debt$6,741 $5,186 
(1)    The fair values of the Apache notes and debentures were $4.3 billion at each of June 30, 2024 and December 31, 2023.
The Company uses a market approach to determine the fair values of its notes and debentures using estimates provided by an independent investment financial data services firm (a Level 2 fair value measurement).
(2)    The carrying value of borrowings on the term loan facility, commercial paper and credit facilities approximates fair value because interest rates are variable and reflective of market rates.
At each of June 30, 2024 and December 31, 2023, current debt included $2 million of finance lease obligations.
Financing Costs, Net
The following table presents the components of the Company’s financing costs, net:
 
For the Quarter Ended
June 30,
For the Six Months Ended
June 30,
 2024202320242023
 (In millions)
Interest expense$108 $89 $193 $177 
Amortization of debt issuance costs2 1 3 2 
Capitalized interest(7)(5)(14)(11)
Gain on extinguishment of debt
   (9)
Interest income(3)(3)(6)(5)
Financing costs, net$100 $82 $176 $154 
During the six months ended June 30, 2023, Apache purchased in the open market and canceled senior notes issued under its indentures in an aggregate principal amount of $74 million for an aggregate purchase price of $65 million in cash. The Company recognized a $9 million gain on these repurchases.
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Unsecured 2022 Committed Credit Facilities
On April 29, 2022, the Company entered into two unsecured syndicated credit agreements for general corporate purposes.
One agreement is denominated in US dollars (the USD Agreement) and provides for an unsecured five-year revolving credit facility, with aggregate commitments of US$1.8 billion (including a letter of credit subfacility of up to US$750 million, of which US$150 million currently is committed). The Company may increase commitments up to an aggregate US$2.3 billion by adding new lenders or obtaining the consent of any increasing existing lenders. This facility matures in April 2027, subject to the Company’s two, one-year extension options.
The second agreement is denominated in pounds sterling (the GBP Agreement) and provides for an unsecured five-year revolving credit facility, with aggregate commitments of £1.5 billion for loans and letters of credit. This facility matures in April 2027, subject to the Company’s two, one-year extension options.

Apache may borrow under the USD Agreement up to an aggregate principal amount of US$300 million outstanding at any given time. Apache has guaranteed obligations under each of the USD Agreement and GBP Agreement effective until the aggregate principal amount of indebtedness under senior notes and debentures outstanding under Apache’s existing indentures first is less than US$1.0 billion.
As of June 30, 2024, there were $395 million of borrowings under the USD Agreement and an aggregate £348 million in letters of credit outstanding under the GBP Agreement. As of June 30, 2024, there were no letters of credit outstanding under the USD Agreement. As of December 31, 2023, there were $372 million of borrowings under the USD Agreement and an aggregate £348 million in letters of credit outstanding under the GBP Agreement. As of December 31, 2023, there were no letters of credit outstanding under the USD Agreement.
Uncommitted Lines of Credit
Each of the Company and Apache, from time to time, has and uses uncommitted credit and letter of credit facilities for working capital and credit support purposes. As of June 30, 2024 and December 31, 2023, there were no outstanding borrowings under these facilities. As of June 30, 2024, there were £416 million and $11 million, respectively, in letters of credit outstanding under these facilities. As of December 31, 2023, there were £416 million and $2 million, respectively, in letters of credit outstanding under these facilities.
Commercial Paper Program
In December 2023, the Company established a commercial paper program under which it from time to time may issue in private placements exempt from registration under the Securities Act short-term unsecured promissory notes (CP Notes) up to a maximum aggregate face amount of $1.8 billion outstanding at any time. The maturities of CP Notes may vary but may not exceed 397 days from the date of issuance. Outstanding CP Notes are supported by available borrowing capacity under the Company’s committed $1.8 billion USD Agreement.
Payment of CP Notes has been unconditionally guaranteed on an unsecured basis by Apache, such guarantee effective until the first time that the aggregate principal amount of indebtedness under senior notes and debentures outstanding under Apache’s existing indentures is less than US$1.0 billion.
As of June 30, 2024, there was $40 million in aggregate face amount of CP Notes outstanding, which is classified as long-term debt. As of December 31, 2023, there were no CP Notes outstanding.
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Unsecured Committed Term Loan Facility
On January 30, 2024, APA entered into a syndicated credit agreement under which the lenders committed an aggregate $2.0 billion for senior unsecured delayed-draw term loans to APA (Term Loan Credit Agreement), the proceeds of which could be used to refinance certain indebtedness of Callon only once upon the date of the closings under the Merger Agreement and Term Loan Credit Agreement. Of such aggregate commitments, $1.5 billion was for term loans that would mature three years after the date of such closings (3-Year Tranche Loans) and $500 million was for term loans that would mature 364 days after the date of such closings (364-Day Tranche Loans). Apache has guaranteed obligations under the Term Loan Credit Agreement effective until the aggregate principal amount of indebtedness under senior notes and debentures outstanding under Apache’s existing indentures first is less than $1.0 billion.
On April 1, 2024, APA closed the transactions under the Term Loan Credit Agreement, electing to borrow an aggregate $1.5 billion in 3-Year Tranche Loans maturing April 1, 2027 and to allow the lender commitments for the 364-Day Tranche Loans to expire.
Loan proceeds were used to refinance certain indebtedness of Callon upon the substantially simultaneous closing of APA’s acquisition of Callon pursuant to the Merger Agreement and to pay related fees and expenses. APA may at any time prepay loans under the Term Loan Credit Agreement. As of June 30, 2024, $1.5 billion in 3-Year Tranche Loans remained outstanding under the Term Loan Credit Agreement.
Indebtedness of Callon that APA could refinance by borrowing under the Term Loan Credit Agreement included indebtedness outstanding under (i) the Amended and Restated Credit Agreement, dated October 19, 2022, among Callon, JPMorgan Chase Bank, N.A., as administrative agent, and the lenders party thereto (Callon Credit Agreement), (ii) Callon’s 6.375% Senior Notes due 2026 (Callon’s 2026 Notes), (iii) Callon’s 8.00% Senior Notes due 2028 (Callon’s 2028 Notes), and (iv) Callon’s 7.500% Senior Notes due 2030 (Callon’s 2030 Notes).
On April 1, 2024, all indebtedness under the Callon Credit Agreement and Callon’s 2026 Notes was repaid, and the aggregate principal balance remaining outstanding under Callon’s 2028 Notes and Callon’s 2030 Notes was reduced to $24 million. On May 6, 2024, all remaining indebtedness under Callon’s 2028 Notes and Callon’s 2030 Notes was repaid. Given these repayments, no guarantee by Callon of APA’s obligations under the Term Loan Credit Agreement is required.
On April 1, 2024, the following Callon indebtedness was repaid by borrowings under the Term Loan Credit Agreement and the USD Agreement:
Callon closed cash tender offers for Callon’s 2028 Notes and Callon’s 2030 Notes, accepting for purchase $1.2 billion aggregate principal amount of notes. Callon paid holders an aggregate $1.3 billion in cash, reflecting principal, premium to par, early tender consent fee, and accrued and unpaid interest.
Callon redeemed the outstanding $321 million principal amount of Callon’s 2026 Notes at a redemption price equal to 101.063% of their principal amount, plus accrued and unpaid interest to the redemption date.
Callon repaid the aggregate $472 million owed under the Callon Credit Agreement, including principal, accrued and unpaid interest, and certain fees.
On May 6, 2024, Callon fully redeemed the remaining outstanding $8 million principal amount of Callon’s 2028 Notes at a redemption price equal to 101.588% of their principal amount and $16 million principal amount of Callon’s 2030 Notes at a redemption price equal to 102.803% of their principal amount, in each case, plus accrued and unpaid interest to the redemption date. The repayments were partially funded by borrowing under the USD Agreement.
10.    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 on 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.
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The Company’s effective income tax rate for the three and six months ended June 30, 2024 differed from the U.S. federal statutory income tax rate of 21 percent due to taxes on foreign operations. During the second quarter of 2023, the Company’s effective income tax rate differed from the U.S. federal statutory income tax rate of 21 percent due to taxes on foreign operations and a decrease in the amount of valuation allowance against its U.S. deferred tax assets. The Company’s effective income tax rate for the six months ended June 30, 2023 differed from the U.S. federal statutory income tax rate of 21 percent due to taxes on foreign operations, a deferred tax expense related to the remeasurement of taxes in the U.K. as a result of the enactment of Finance Act 2023, and a decrease in the amount of valuation allowance against its U.S. deferred tax assets.
On April 1, 2024, APA completed its acquisition of Callon in an all-stock transaction. The Company’s deferred tax asset increased by approximately $575 million as part of the assets assumed through the Callon acquisition. Refer to Note 2—Acquisitions and Divestitures for further detail.
In December 2021, the Organisation for Economic Co-operation and Development issued Pillar Two Model Rules introducing a new global minimum tax of 15 percent on a country-by-country basis, with certain aspects effective in certain jurisdictions on January 1, 2024. Although the Company continues to monitor enacted legislation to implement these rules in countries where the Company could be impacted, APA does not expect that the Pillar Two framework will have a material impact on its consolidated financial statements.
The Company and its subsidiaries are subject to U.S. federal income tax as well as income or capital taxes in various states and foreign jurisdictions. The Company’s tax reserves are related to tax years that may be subject to examination by the relevant taxing authority.
11.    COMMITMENTS AND CONTINGENCIES
Legal Matters
The Company is party to various legal actions arising in the ordinary course of business, including litigation and governmental and regulatory controls, which also may include controls related to the potential impacts of climate change. As of June 30, 2024, the Company has an accrued liability of approximately $76 million for all legal contingencies that are deemed to be probable of occurring and can be reasonably estimated. The Company’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 the Company’s financial position, results of operations, or liquidity after consideration of recorded accruals. With respect to material matters for which the Company 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 Legal Matters described below, refer to Note 11—Commitments and Contingencies to the consolidated financial statements contained in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2023.
Argentine Environmental Claims
On March 12, 2014, the Company and its subsidiaries completed the sale of all of the Company’s subsidiaries’ operations and properties in Argentina to YPF Sociedad Anonima (YPF). As part of that sale, YPF assumed responsibility for all of the past, present, and future litigation in Argentina involving Company subsidiaries, except that Company subsidiaries have agreed to indemnify YPF for certain environmental, tax, and royalty obligations capped at an aggregate of $100 million. The indemnity is subject to specific agreed conditions precedent, thresholds, contingencies, limitations, claim deadlines, loss sharing, and other terms and conditions. On April 11, 2014, YPF provided its first notice of claims pursuant to the indemnity. Company subsidiaries have not paid any amounts under the indemnity but will continue to review and consider claims presented by YPF. Further, Company subsidiaries retain the right to enforce certain Argentina-related indemnification obligations against Pioneer Natural Resources Company (Pioneer) in an amount up to $45 million pursuant to the terms and conditions of stock purchase agreements entered in 2006 between Company subsidiaries and subsidiaries of Pioneer.
19


Louisiana Restoration 
As more fully described in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2023, Louisiana surface owners often file lawsuits or assert claims against oil and gas companies, including the Company, 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. Further, the overall exposure related to these lawsuits and claims is not currently determinable. While adverse judgments against the Company are possible, the Company intends to actively defend these lawsuits and claims.
Starting in November of 2013 and continuing into 2023, several parishes in Louisiana have pending lawsuits against many oil and gas producers, including the Company. 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 condi