NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
These consolidated financial statements have been prepared by Apache Corporation (Apache or the Company) without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). They reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the results for the interim periods, on a basis consistent with the annual audited financial statements, with the exception of 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 became a direct, wholly owned subsidiary of APA Corporation (APA), and all of Apache’s outstanding shares automatically converted into equivalent corresponding shares of APA. Pursuant to the Holding Company Reorganization, APA became the successor issuer to Apache pursuant to Rule 12g-3(a) under the Exchange Act and replaced Apache 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, making it more consistent with other companies that have affiliates operating around the globe. Refer to Note 2—Transactions with Parent Affiliate for more detail. 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
As of June 30, 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 Apache and its subsidiaries after elimination of intercompany balances and transactions. Apache’s consolidated financial statements reflect the impacts of the Holding Company Reorganization on a prospective basis, and results prior to completion of the Holding Company Reorganization have not been restated. Refer to Note 2—Transactions with Parent Affiliate for more detail. 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 Apache and are reflected separately in the Company’s financial statements.
In conjunction with the ratification of a new merged concession agreement with the Egyptian General Petroleum Corporation (EGPC) in December 2021, Apache modified partnership agreements for certain consolidated subsidiaries. Apache subsequently determined that one of its limited partnership subsidiaries, which has control over Apache’s Egyptian operations, qualified as a variable interest entity (VIE) under GAAP. Apache continues to consolidate this limited partnership subsidiary because the Company has concluded that it has a controlling financial interest in the Egyptian operations and was determined to be the primary beneficiary of the VIE. For all periods presented, Sinopec International Petroleum Exploration and Production Corporation (Sinopec) has owned a one-third minority participation in the Company’s consolidated Egypt oil and gas business as a noncontrolling interest. Under the modified partnership agreements, APA owns a minority participation in the remaining two-thirds of its consolidated Egypt oil and gas business as a noncontrolling interest. Refer to Note 2—Transactions with Parent Affiliate for detail regarding APA’s noncontrolling interest. All noncontrolling interests are reflected as a separate 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 VIE under GAAP, which Apache consolidated because a wholly owned subsidiary of Apache 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.
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 VIE under GAAP. As a result, the Company deconsolidated ALTM on February 22, 2022. Refer to Note 3—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 7—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 3—Acquisitions and Divestitures), the fair value of equity method interests (refer to “Equity Method Interests” within this Note 1 below and Note 7—Equity Method Interests), the assessment of asset retirement obligations (refer to Note 9—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 12—Commitments and Contingencies), the estimate of income taxes (refer to Note 11—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).
During the three and six months ended June 30, 2022 and 2021, the Company recorded no asset impairments in connection with fair value assessments.
Accounts Receivable from / Accounts Payable to APA
Accounts receivable from or payable to APA represents the net result of Apache’s administrative and support services provided to APA and other miscellaneous cash management transactions to be settled between the two affiliated entities. Generally, cash in this amount will be transferred to Apache or paid to APA in subsequent periods, after current period transactions are processed and net results of operations are determined. However, from time to time, Apache may estimate and transfer the cash settlement amount in the month the transactions are processed in order to minimize affiliate working capital balances. Refer to Note 2—Transactions with Parent Affiliate for more detail. Revenue Recognition
There have been no significant changes to the Company’s contracts with customers during the six months ended June 30, 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, including receivables for purchased oil and gas sales and net of allowance for credit losses, were $1.8 billion and $1.3 billion as of June 30, 2022 and December 31, 2021, respectively.
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.
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.
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 3—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 Apache-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. TRANSACTIONS WITH PARENT AFFILIATE
The Company completed the Holding Company Reorganization on March 1, 2021 and sold to APA all of the equity in the three Apache subsidiaries through which Apache’s interests in Suriname and the Dominican Republic were held. The Company accounted for the divestiture of its subsidiaries as a transfer to an affiliate entity under common control and no longer consolidates the subsidiaries for periods subsequent to the Holding Company Reorganization. The carrying value of the net assets transferred was $483 million, which included approximately $292 million of cash and cash equivalents, $163 million of oil and gas properties, and working capital items. The Company continues to hold its existing assets in the U.S., Egypt, and the U.K.
The Holding Company Reorganization gave rise to a note payable by APA to Apache. The note has a seven-year term, maturing on February 29, 2028, and bears interest at a rate of 4.5 percent per annum, payable semi-annually, subject to APA’s option to allow accrued interest to convert to principal (PIK) during the first 5.5 years of the note’s term (to August 31, 2026). The note is guaranteed by each of the three subsidiaries sold by Apache to APA. The Company recognized interest income on this note of $16 million and $15 million during the second quarters of 2022 and 2021, respectively, and $31 million and $20 million during the first six months of 2022 and 2021, respectively. The interest income related to this note is reflected in “Financing costs, net” on the Company’s statement of consolidated operations. Apache has allowed interest accrued from March 1, 2021 through February 28, 2022, totaling $61 million, to PIK pursuant to the note.
In the fourth quarter of 2021, in conjunction with the ratification of a new merged concession agreement (MCA) with EGPC, Apache entered into an agreement with APA under which the historical value of existing concessions prior to ratifying the MCA was retained by Apache, with any excess value from the MCA terms being allocated to APA. Sinopec owns a one-third minority participation in the Company’s consolidated Egypt oil and gas business, and approximately 30 percent of the remaining net income and distributable cash flow for the Company’s Egyptian operations is being allocated to APA in 2022. Apache consolidates its Egyptian operations, with APA’s noncontrolling interest reflected as a separate component in the Company’s consolidated balance sheet. In the second quarter and the first six months of 2022, the Company recorded net income attributable to APA’s noncontrolling interest of $85 million and $156 million, respectively, and distributed $95 million in the first six months of 2022 of cash to APA in association with its noncontrolling interest.
The Company continues to provide administrative and support operations to APA related to activities performed for the Suriname and Dominican Republic subsidiaries. The Company is reimbursed by APA for employee costs, certain internal costs, and third-party costs paid by the Company in connection with its role as service provider. All reimbursements are based on actual costs incurred, and no market premium is applied by the Company to APA. The Company incurred $5 million and $9 million in reimbursable corporate overhead charges in the second quarter and the first six months of 2022, respectively.
In August 2021, Apache entered into a promissory note with APA under which Apache may borrow up to $250 million from APA at APA’s discretion. The note has a term of one year, maturing on August 4, 2022, and bears interest at a variable rate per annum equal to the monthly, short-term applicable federal rate, payable semi-annually. As of June 30, 2022, there were no borrowings outstanding under this note. As of December 31, 2021, there was $195 million outstanding under this note, which was reflected as “Note payable to APA Corporation” on the Company’s consolidated balance sheet.
In April 2022, Apache made a promissory note payable to APA in the original principal amount of $680 million. Apache made the note in consideration for APA’s assumption under its U.S. dollar denominated syndicated facility on April, 29, 2022 of Apache’s borrowings outstanding upon the simultaneous termination of its 2018 syndicated facility, as described in Note 10—Debt and Financing Costs. The non-interest-bearing note has a term of one year, maturing on April 28, 2023. Apache repaid $331 million on the note during the second quarter, and the outstanding balance of $349 million as of June 30, 2022 is reflected as “Note payable to APA Corporation” on the Company’s consolidated balance sheet. From time to time, the Company may, at its discretion, make distributions of capital to APA Corporation. During the first six months of 2022, the Company made capital distributions totaling $733 million primarily in support of APA Corporation’s share repurchase program, dividend payments made by APA, and distributions for APA’s noncontrolling interest during the period. No capital distributions were made in the first six months of 2021.
3. ACQUISITIONS AND DIVESTITURES
2022 Activity
During the second quarter of 2022, the Company completed leasehold and property acquisitions, primarily in the Permian Basin, for total cash consideration of $26 million. During the second quarter of 2022, the Company also completed the sale of non-core assets and leasehold in multiple transactions for total cash proceeds of $7 million, recognizing a gain of approximately $1 million upon closing of these transactions.
During the first quarter of 2022, the Company completed a previously announced transaction to sell certain non-core mineral rights in the Delaware Basin. The Company received total cash proceeds of approximately $736 million after certain post-closing adjustments and recognized an associated gain of approximately $563 million. 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 $1 million upon closing of these transactions during the first quarter of 2022.
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.
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 assets | | 29 | |
| Property and equipment, net | | 184 | |
| Equity method interests | | 1,367 | |
| Other noncurrent assets | | 12 | |
| Total assets deconsolidated | | $ | 1,735 | |
| | |
| LIABILITIES: | | |
| Current liabilities | | $ | 3 | |
| Long-term debt | | 657 | |
| Other noncurrent liabilities | | 168 | |
| Total liabilities deconsolidated | | $ | 828 | |
| | |
| NONCONTROLLING INTERESTS: | | |
| Redeemable noncontrolling interest preferred unit limited partners | | $ | 642 | |
| Noncontrolling interest-Altus | | 72 | |
| Total noncontrolling interests deconsolidated | | $ | 714 | |
| | |
| Net effect of deconsolidating balance sheet | | $ | (193) | |
| | |
| Gain on deconsolidation of ALTM | | $ | 609 | |
| | |
During the first quarter of 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 7—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. 2021 Activity
During the second quarter of 2021, the Company completed the sale of certain non-core assets in the Permian Basin with a net carrying value of $157 million, for cash proceeds of $178 million and the assumption of asset retirement obligations of $44 million. The Company recognized a gain of approximately $65 million in connection with the sale.
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.
4. CAPITALIZED EXPLORATORY WELL COSTS
The Company’s capitalized exploratory well costs were $78 million and $46 million as of June 30, 2022 and December 31, 2021, respectively. The increase is primarily attributable to additional drilling activity, offset by successful transfer of well costs. No suspended exploratory well costs previously capitalized for greater than one year at December 31, 2021 were charged to dry hole expense during the six months ended June 30, 2022.
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.
5. 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 June 30, 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.
Derivative Instruments
Commodity Derivative Instruments
As of June 30, 2022, the Company had the following open natural gas financial basis swap contracts:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Basis Swap Purchased | | Basis Swap Sold |
| Production Period | | Settlement Index | | MMBtu
(in 000’s) | | Weighted Average Price Differential | | MMBtu
(in 000’s) | | Weighted Average Price Differential |
| July—December 2022 | | NYMEX Henry Hub/IF Waha | | 42,320 | | | $(0.70) | | — | | | — |
| July—December 2022 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 42,320 | | | $(0.12) |
| October—December 2022 | | NYMEX Henry Hub/IF Waha | | 920 | | | $(1.19) | | — | | | — |
| October—December 2022 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 920 | | | $(0.19) |
| January—March 2023 | | NYMEX Henry Hub/IF Waha | | 3,150 | | | $(1.06) | | — | | | — |
| January—March 2023 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 3,150 | | | $(0.03) |
| January—June 2023 | | NYMEX Henry Hub/IF Waha | | 4,525 | | | $(1.54) | | — | | | — |
| January—June 2023 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 4,525 | | | $(0.11) |
| July—September 2023 | | NYMEX Henry Hub/IF Waha | | 1,840 | | | $(1.62) | | — | | | — |
| July—September 2023 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 1,840 | | | $(0.19) |
| January—December 2023 | | NYMEX Henry Hub/IF Waha | | 73,000 | | | $(1.15) | | — | | | — |
| January—December 2023 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 73,000 | | | $(0.08) |
| January—June 2024 | | NYMEX Henry Hub/IF Waha | | 3,640 | | | $(1.25) | | — | | | — |
| January—June 2024 | | NYMEX Henry Hub/IF HSC | | — | | | — | | 3,640 | | | $(0.10) |
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 $1.29 and $1.39, respectively.
Embedded Derivatives
Altus Preferred Units 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.
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, 2022 | | | | | | | | | | | | |
| Assets: | | | | | | | | | | | | |
| Commodity derivative instruments | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | 1 | | | $ | 1 | |
| Liabilities: | | | | | | | | | | | | |
| Commodity derivative instruments | | — | | | 54 | | | — | | | 54 | | | 1 | | | 55 | |
| Foreign currency derivative instruments | | — | | | 7 | | | — | | | 7 | | | — | | | 7 | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
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:
| | | | | | | | | | | | | | |
| | June 30, 2022 | | December 31, 2021 |
| | | | |
| | (In millions) |
| Current Assets: Other current assets | | $ | — | | | $ | — | |
| Other Assets: Deferred charges and other | | 1 | | | — | |
| Total derivative assets | | $ | 1 | | | $ | — | |
| | | | |
| Current Liabilities: Other current liabilities | | $ | 41 | | | $ | 4 | |
| Deferred Credits and Other Noncurrent Liabilities: Other | | 21 | | | 109 | |
| Total derivative liabilities | | $ | 62 | | | $ | 113 | |
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, |
| 2022 | | 2021 | | 2022 | | 2021 |
| | | | | | | | |
| | | (In millions) |
| Realized: | | | | | | | | |
| Commodity derivative instruments | | $ | (4) | | | $ | (48) | | | $ | (9) | | | $ | 100 | |
| Foreign currency derivative instruments | | (2) | | | — | | | (2) | | | — | |
| Realized gain (loss), net | | (6) | | | (48) | | | (11) | | | 100 | |
| Unrealized: | | | | | | | | |
| Commodity derivative instruments | | (20) | | | (98) | | | (44) | | | (72) | |
| Pipeline capacity embedded derivatives | | — | | | 2 | | | — | | | 3 | |
| Foreign currency derivative instruments | | (6) | | | — | | | (8) | | | — | |
| Preferred Units embedded derivative | | — | | | 31 | | | (31) | | | 14 | |
| Unrealized loss, net | | (26) | | | (65) | | | (83) | | | (55) | |
| Derivative instrument gains (losses), net | | $ | (32) | | | $ | (113) | | | $ | (94) | | | $ | 45 | |
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.
6. OTHER CURRENT ASSETS
The following table provides detail of the Company’s other current assets:
| | | | | | | | | | | | | | |
| | June 30, 2022 | | December 31, 2021 |
| | | | |
| | | (In millions) |
| Inventories | | $ | 437 | | | $ | 438 | |
| Drilling advances | | 57 | | | 55 | |
| | | | |
| Prepaid assets and other | | 27 | | | 56 | |
| Current decommissioning security for sold Gulf of Mexico assets | | 350 | | | 100 | |
| Total Other current assets | | $ | 871 | | | $ | 649 | |
7. EQUITY METHOD INTERESTS
The Kinetik Class A Common Stock held by the Company is treated as an interest in equity securities measured at fair value. 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 is determined using observable share prices on a major exchange, a Level 1 fair value measurement. Fair value adjustments and dividends received are recorded as a component of “Other, net” under “Revenues and other” in the Company’s statement of consolidated operations.
The initial interest in Kinetik was measured at fair value based on the Company’s ownership of approximately 12.9 million shares of Kinetik Class A Common stock as of February 22, 2022. In March 2022, the Company sold four million of its shares of Kinetik Class A Common Stock for a loss, including underwriters fees, of $25 million, which was recorded as a component of “Gain on divestitures, net” under “Revenues and other” in the Company’s statement of consolidated operations. Refer to Note 3—Acquisitions and Divestitures for further detail. A fair value adjustment gain of $24 million was recorded during the first quarter of 2022 based on the Company’s remaining 8.9 million shares of Kinetik Class A Common Stock as of March 31, 2022. During the second quarter of 2022, Kinetik issued a two-for-one split of its Common Stock. Also during the second quarter, the Company received approximately 0.4 million shares of Kinetik’s Class A Common Stock as a paid-in-kind dividend. A fair value adjustment gain of $29 million was recorded during the second quarter based on the Company’s ownership of 18.1 million shares of Kinetik Class A Common Stock on June 30, 2022.
The Company’s ownership represented approximately 13 percent of Kinetik’s outstanding Class A Common Stock, as of March 31, 2022 and June 30, 2022.
The following table presents the activity in the Company’s equity method interest in Kinetik for the six months ended June 30, 2022:
| | | | | | | | |
| | Kinetik Holdings Inc |
| | |
| (In millions) |
Balance at December 31, 2021 | | $ | — | |
| Initial interest upon closing the BCP Business Combination | | 802 | |
| Sale of Class A shares | | (250) | |
| Paid-in-kind dividend | | 13 | |
| Fair value adjustments | | 53 | |
Balance at June 30, 2022 | | $ | 618 | |
During the three and six months ending June 30, 2022, the Company recorded GPT costs for midstream services provided by Kinetik subsequent to the close of the transaction totaling $26 million and $36 million, respectively. As of June 30, 2022, the Company has recorded accrued GPT costs payable to Kinetik of approximately $8 million.
Prior to the deconsolidation of Altus on February 22, 2022, the Company, through its ownership of Altus, had the following equity method interests in four Permian Basin long-haul pipeline entities, which were accounted for under the equity method of accounting at December 31, 2021. For each of the equity method interests, Altus had the ability to exercise significant influence based on certain governance provisions and its participation in activities and decisions that impact the management and economic performance of the equity method interests. The table below presents the ownership percentages held by the Company and associated carrying values for each entity:
| | | | | | | | | | | | | | |
| | Interest | | December 31, 2021 |
| | | | (In millions) |
| Gulf Coast Express Pipeline, LLC | | 16.0% | | $ | 274 | |
| EPIC Crude Holdings, LP | | 15.0% | | — | |
| Permian Highway Pipeline, LLC | | 26.7% | | 630 | |
| Shin Oak Pipeline (Breviloba, LLC) | | 33.0% | | 461 | |
| Total Altus equity method interests | | | | $ | 1,365 | |
The following table presents the activity in Altus’ equity method interests for the six months ended June 30, 2022:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Gulf Coast Express
Pipeline LLC | | EPIC Crude
Holdings, LP | | Permian Highway
Pipeline LLC | | Breviloba, LLC | | Total |
| | | | | | | | | | |
| | (In millions) |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
Balance at December 31, 2021 | | $ | 274 | | | $ | — | | | $ | 630 | | | $ | 461 | | | $ | 1,365 | |
| Capital contributions | | — | | | 2 | | | — | | | — | | | 2 | |
| Distributions | | (5) | | | — | | | (9) | | | (7) | | | (21) | |
| | | | | | | | | | |
| Equity income (loss), net | | 8 | | | (2) | | | 10 | | | 5 | | | 21 | |
| | | | | | | | | | |
| Deconsolidation of Altus | | (277) | | | — | | | (631) | | | (459) | | | (1,367) | |
Balance at June 30, 2022 | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
8. OTHER CURRENT LIABILITIES
The following table provides detail of the Company’s other current liabilities:
| | | | | | | | | | | | | | |
| | June 30, 2022 | | December 31, 2021 |
| | | | |
| | | (In millions) |
| Accrued operating expenses | | $ | 145 | | | $ | 129 | |
| Accrued exploration and development | | 263 | | | 206 | |
| Accrued compensation and benefits | | 281 | | | 292 | |
| Accrued interest | | 95 | | | 107 | |
| Accrued income taxes | | 180 | | | 28 | |
| Current asset retirement obligation | | 40 | | | 41 | |
| Current operating lease liability | | 120 | | | 99 | |
| Current portion of derivatives at fair value | | 41 | | | 4 | |
| Current decommissioning contingency for sold Gulf of Mexico properties | | 350 | | | 100 | |
| Other | | 206 | | | 164 | |
| Total Other current liabilities | | $ | 1,721 | | | $ | 1,170 | |
9. ASSET RETIREMENT OBLIGATION
The following table describes changes to the Company’s asset retirement obligation (ARO) liability:
| | | | | | | | |
| | June 30, 2022 |
| | | (In millions) |
Asset retirement obligation, December 31, 2021 | | $ | 2,130 | |
| Liabilities incurred | | 2 | |
| Liabilities settled | | (16) | |
| Liabilities divested | | (4) | |
| Deconsolidation of Altus | | (69) | |
| | |
| Accretion expense | | 58 | |
| | |
Asset retirement obligation, June 30, 2022 | | 2,101 | |
| Less current portion | | (40) | |
| Asset retirement obligation, long-term | | $ | 2,061 | |
10. DEBT AND FINANCING COSTS
The following table presents the carrying values of the Company’s debt:
| | | | | | | | | | | | | | |
| | June 30, 2022 | | December 31, 2021 |
| | (In millions) |
Notes and debentures before unamortized discount and debt issuance costs(1) | | $ | 5,032 | | | $ | 6,344 | |
Altus credit facility(2) | | — | | | 657 | |
Syndicated credit facility(2) | | — | | | 542 | |
| Finance lease obligations | | 35 | | | 36 | |
| Unamortized discount | | (28) | | | (30) | |
| Debt issuance costs | | (29) | | | (39) | |
| Total debt | | 5,010 | | | 7,510 | |
| Current maturities | | (125) | | | (215) | |
| Long-term debt | | $ | 4,885 | | | $ | 7,295 | |
(1) The fair values of the Company’s notes and debentures were $4.4 billion and $7.1 billion as of June 30, 2022 and December 31, 2021, respectively.
Apache 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 credit facilities approximates fair value because interest rates are variable and reflective of market rates.
As of June 30, 2022, current debt included $123 million carrying value of 2.625% senior notes due January 15, 2023 and $2 million of finance lease obligations. As of December 31, 2021, current debt included $213 million carrying value of 3.25% senior notes due April 15, 2022 and $2 million of finance lease obligations.
During the quarter ended March 31, 2022, Apache closed cash tender offers for certain outstanding notes issued under its indentures, accepting for purchase $1.1 billion aggregate principal amount of notes. Apache paid holders an aggregate $1.2 billion in cash, reflecting principal, premium to par, and accrued and unpaid interest. The Company recognized a $66 million loss on extinguishment of debt, including $11 million of unamortized debt discount and issuance costs in connection with the note purchases.
During the quarter ended March 31, 2022, Apache purchased in the open market and canceled senior notes issued under its indentures in an aggregate principal amount of $15 million for an aggregate purchase price of $16 million in cash, including accrued interest and broker fees, reflecting a premium to par of $1 million. The Company recognized a $1 million loss on these repurchases.
During the quarter ended March 31, 2022, Apache redeemed the outstanding $213 million principal amount of 3.25% senior notes due April 15, 2022, at a redemption price equal to 100% of their principal amount, plus accrued and unpaid interest to the redemption date. The redemption was financed by borrowing under Apache’s revolving credit facility.
Apache intends to reduce debt outstanding under its indentures from time to time.
On April 29, 2022, Apache entered into two unsecured guaranties of obligations under two unsecured syndicated credit agreements then entered into by APA Corporation (APA), of which Apache is a wholly owned subsidiary. APA’s new credit agreements are for general corporate purposes and replaced and refinanced Apache’s 2018 syndicated credit agreement (the Former Facility).
•APA’s first new credit 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). APA 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 APA’s two, one-year extension options.
•APA’s second new credit 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 APA’s two, one-year extension options.
In connection with APA’s entry into the USD Agreement and the GBP Agreement (each, a New Agreement), Apache terminated US$4.0 billion of commitments under the Former Facility, borrowings then outstanding under the Former Facility were deemed outstanding under APA’s USD Agreement, and letters of credit then outstanding under the Former Facility were deemed outstanding under a New Agreement, depending upon whether denominated in US dollars or pounds sterling. Apache has guaranteed obligations under each New Agreement effective until the aggregate principal amount of indebtedness under senior notes and debentures outstanding under Apache’s existing indentures is less than US$1.0 billion.
Apache may borrow under APA’s USD Agreement up to an aggregate principal amount of US$300 million outstanding at any given time. As of June 30, 2022, there were no borrowings by Apache outstanding under the USD Agreement. As of December 31, 2021, there were $542 million of borrowings and an aggregate £748 million and $20 million in letters of credit outstanding under the Former Facility.
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, 2022 and December 31, 2021, there were no outstanding borrowings under these facilities. As of June 30, 2022, there were £117 million and $17 million in letters of credit outstanding under these facilities. As of December 31, 2021, there were £117 million and $17 million in letters of credit outstanding under these facilities.
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, |
| | | 2022 | | 2021 | | 2022 | | 2021 |
| | | (In millions) |
| Interest expense | | $ | 75 | | | $ | 110 | | | $ | 165 | | | $ | 222 | |
| Amortization of debt issuance costs | | 4 | | | 3 | | | 6 | | | 5 | |
| Capitalized interest | | (1) | | | — | | | (1) | | | — | |
| (Gain) loss on extinguishment of debt | | — | | | (1) | | | 67 | | | (1) | |
| Interest income | | (1) | | | (3) | | | (5) | | | (5) | |
| Interest income from APA Corporation, net | | (15) | | | (15) | | | (30) | | | (20) | |
| Financing costs, net | | $ | 62 | | | $ | 94 | | | $ | 202 | | | $ | 201 | |
11. 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.
During the second quarter of 2022, the Company’s effective income tax rate was primarily impacted by a decrease in the amount of valuation allowance against its U.S. deferred tax assets. The Company’s 2022 year-to-date effective income tax rate was primarily impacted by the gain associated with deconsolidation of Altus, the gain on sale of certain non-core mineral rights in the Delaware Basin, and a decrease in the amount of valuation allowance against its U.S. deferred tax assets. During the second quarter and the first six months of 2021, the Company’s effective income tax rate was primarily impacted by a decrease in the amount of valuation allowance against its U.S. deferred tax assets.
On May 26, 2022, the U.K. Chancellor announced a new tax on the profits of oil and gas companies operating in the U.K. and the U.K. Continental Shelf. On June 21, 2022, the U.K. Government published draft legislation concerning this new tax and on July 14, 2022, the Energy (Oil and Gas) Profits Levy Act 2022 was enacted, receiving Royal Assent. Under the new law, an additional levy is assessed at a 25 percent tax rate and will be effective for the period of May 26, 2022, through December 31, 2025. Under U.S. GAAP, the financial statement impact of new legislation will be recorded in the period of enactment. Therefore, in the third quarter of 2022, the Company expects to record a deferred tax expense of approximately $230 million to $250 million related to the remeasurement of the June 30, 2022 U.K. deferred tax liability.
The Company is subject to U.S. federal income tax as well as income or capital taxes in various state and foreign jurisdictions. The Company’s tax reserves are related to tax years that may be subject to examination by the relevant taxing authority. The Company is currently under audit by the Internal Revenue Service for the 2014-2017 tax years and is also under audit in various states and foreign jurisdictions as part of its normal course of business.
12. 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, 2022, the Company has an accrued liability of approximately $48 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. For material matters that 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, 2021.
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.
Louisiana Restoration
As more fully described in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2021, 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 2022, several parishes in Louisiana have pending lawsuits against many oil and gas producers, including the Company. These cases were all removed to federal courts in Louisiana. In these cases, the Parishes, as plaintiffs, allege that defendants’ oil and gas exploration, production, and transportation operations in specified fields were conducted in violation of the State and Local Coastal Resources Management Act of 1978, as amended, and applicable regulations, rules, orders, and ordinances promulgated or adopted thereunder by the Parish or the State of Louisiana. Plaintiffs allege that defendants caused substantial damage to land and water bodies located in the coastal zone of Louisiana. Plaintiffs seek, among other things, unspecified damages for alleged violations of applicable law within the coastal zone, the payment of costs necessary to clear, re-vegetate, detoxify, and otherwise restore the subject coastal zone as near as practicable to its original condition, and actual restoration of the coastal zone to its original condition. While adverse judgments against the Company might be possible, the Company intends to vigorously oppose these claims.
Apollo Exploration Lawsuit
In a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation, Cause No. CV50538 in the 385th Judicial District Court, Midland County, Texas, plaintiffs alleged damages in excess of $200 million (having previously claimed in excess of $1.1 billion) relating to purchase and sale agreements, mineral leases, and area of mutual interest agreements concerning properties located in Hartley, Moore, Potter, and Oldham Counties, Texas. The trial court entered final judgment in favor of the Company, ruling that the plaintiffs take nothing by their claims and awarding the Company its attorneys’ fees and costs incurred in defending the lawsuit. The court of appeals affirmed in part and reversed in part the trial court’s judgment thereby reinstating some of plaintiff’s claims. Further appeal is pending.
Australian Operations Divestiture Dispute
Pursuant to a Sale and Purchase Agreement dated April 9, 2015 (Quadrant SPA), the Company and its subsidiaries divested Australian operations to Quadrant Energy Pty Ltd (Quadrant). Closing occurred on June 5, 2015. In April 2017, the Company filed suit against Quadrant for breach of the Quadrant SPA. In its suit, the Company seeks approximately AUD $80 million. In December 2017, Quadrant filed a defense of equitable set-off to the Company’s claim and a counterclaim seeking approximately AUD $200 million in the aggregate. The Company believes that Quadrant’s claims lack merit and will not have a material adverse effect on the Company’s financial position, results of operation, or liquidity.
Canadian Operations Divestiture Dispute
Pursuant to a Sale and Purchase Agreement dated July 6, 2017 (Paramount SPA), the Company and its subsidiaries divested their remaining Canadian operations to Paramount Resources LTD (Paramount). Closing occurred on August 16, 2017. On September 11, 2019, four ex-employees of Apache Canada LTD on behalf of themselves and individuals employed by Apache Canada LTD on July 6, 2017, filed an Amended Statement of Claim in a matter styled Stephen Flesch et. al. v Apache Corporation et. al., No. 1901-09160 Court of Queen’s Bench of Alberta against the Company and others seeking class certification and a finding that the Paramount SPA amounted to a Change of Control of the Company, entitling them to accelerated vesting under the Company’s equity plans. In the suit, the class seeks approximately $60 million USD and punitive damages. The Company believes that Plaintiffs’ claims lack merit and will not have a material adverse effect on the Company’s financial position, results of operation, or liquidity.
California and Delaware Litigation
On July 17, 2017, in three separate actions, San Mateo County, California, Marin County, California, and the City of Imperial Beach, California, all filed suit individually and on behalf of the people of the state of California against over 30 oil and gas companies alleging damages as a result of global warming. Plaintiffs seek unspecified damages and abatement under various tort theories. On December 20, 2017, in two separate actions, the City of Santa Cruz and Santa Cruz County and in a separate action on January 22, 2018, the City of Richmond, filed similar lawsuits against many of the same defendants. On November 14, 2018, the Pacific Coast Federation of Fishermen’s Associations, Inc. also filed a similar lawsuit against many of the same defendants. After removal of all such lawsuits to federal court, the district court remanded them back to state court. The 9th Circuit Court of Appeals’ affirmance of this remand decision was appealed to the U.S. Supreme Court. That appeal was decided by the U.S. Supreme Court ruling in a similar case, BP p.l.c. v. Mayor and City Council of Baltimore. As a result, the California cases were sent back to the 9th Circuit for further appellate review of the decision to remand the cases to state court. The 9th Circuit has since, once again, affirmed the district court’s remand to state court. The defendants are appealing this latest remand decision to the U.S. Supreme Court. Further activity in the cases has been stayed pending further appellate review.
On September 10, 2020, the State of Delaware filed suit, individually and on behalf of the people of the State of Delaware, against over 25 oil and gas companies alleging damages as a result of global warming. Plaintiffs seek unspecified damages and abatement under various tort theories. After removal of this lawsuit to federal court, the district court remanded it back to state court. The remand order is being appealed to the 3rd Circuit Court of Appeals. Further activity in the case has been stayed pending this appellate review.
The Company believes that it is not subject to jurisdiction of the California courts and that claims made against it in the California and Delaware litigation are baseless. The Company intends to challenge jurisdiction in California and to vigorously defend the Delaware lawsuit.
Castex Lawsuit
In a case styled Apache Corporation v. Castex Offshore, Inc., et. al., Cause No. 2015-48580, in the 113th Judicial District Court of Harris County, Texas, Castex filed claims for alleged damages of approximately $200 million, relating to overspend on the Belle Isle Gas Facility upgrade, and the drilling of five sidetracks on the Potomac #3 well. After a jury trial, a verdict of approximately $60 million, plus fees, costs, and interest was entered against the Company. The Fourteenth Court of Appeals of Texas reversed the judgment, in part, reducing the judgment to approximately $13.5 million, plus fees, costs, and interest against the Company. Further appeal is pending.
Oklahoma Class Action
The Company is a party to a purported class action in Oklahoma styled Albert Steven Allen v. Apache Corporation, Case No. CJ-2019-00219.
The Allen case seeks to represent a group of owners who have allegedly received late royalty and other payments under Oklahoma statutes. With no admission of liability or wrongdoing, but only to avoid the expense and uncertainty of future litigation, Apache has entered into a settlement agreement in the Allen case to resolve all claims made against it by the class. The settlement agreement is subject to court approval and a full fairness hearing will be held in the coming months. The settlement will not have a material effect on the Company’s financial position, results of operations, or liquidity.
Shareholder and Derivative Lawsuits
On February 23, 2021, a case captioned Plymouth County Retirement System v. Apache Corporation, et al. was filed in the United States District Court for the Southern District of Texas (Houston Division) against the Company and certain current and former officers. The complaint, which is a shareholder lawsuit styled as a class action, (1) alleges that the Company intentionally used unrealistic assumptions regarding the amount and composition of available oil and gas in Alpine High; (2) alleges that the Company did not have the proper infrastructure in place to safely and/or economically drill and/or transport those resources even if they existed in the amounts purported; (3) alleges that these statements and omissions artificially inflated the value of the Company’s operations in the Permian Basin; and (4) alleges that, as a result, the Company’s public statements were materially false and misleading. The Company believes that plaintiffs’ claims lack merit and intends to vigorously defend this lawsuit.
On March 16, 2021, a case captioned William Wessels, Derivatively and on behalf of APA Corporation v. John J. Christmann IV et al. was filed in the 334th District Court of Harris County, Texas. The case purports to be a derivative action brought against senior management and Company directors over many of the same allegations included in the Plymouth County Retirement System matter and asserts claims of (1) breach of fiduciary duty; (2) waste of corporate assets; and (3) unjust enrichment. On March 17, 2022, the trial court granted Defendants’ Special Exceptions and dismissed the claim with prejudice.
Environmental Matters
As of June 30, 2022, the Company had an undiscounted reserve for environmental remediation of approximately $2 million.
On September 11, 2020, the Company received a Notice of Violation and Finding of Violation, and accompanying Clean Air Act Information Request, from the U.S. Environmental Protection Agency (EPA) following site inspections in April 2019 at several of the Company’s oil and natural gas production facilities in Lea and Eddy Counties, New Mexico. The notice and information request involve alleged emissions control and reporting violations. The Company is cooperating with the EPA and has responded to the information request. The EPA has referred the notice for civil enforcement proceedings; however, at this time the Company is unable to reasonably estimate whether such proceedings will result in monetary sanctions and, if so, whether they would be more or less than $100,000, exclusive of interest and costs.
On December 29, 2020, the Company received a Notice of Violation and Opportunity to Confer, and accompanying Clean Air Act Information Request, from the EPA following helicopter flyovers in September 2019 of several of the Company’s oil and natural gas production facilities in Reeves County, Texas. The notice and information request involve alleged emissions control and reporting violations. The Company is cooperating with the EPA and has responded to the information request. The EPA has referred the notice for civil enforcement proceedings; however, at this time the Company is unable to reasonably estimate whether such proceedings will result in monetary sanctions and, if so, whether they would be more or less than $100,000, exclusive of interest and costs.
The Company is not aware of any environmental claims existing as of June 30, 2022 that have not been provided for or would otherwise have a material impact on its financial position, results of operations, or liquidity. There can be no assurance, however, that current regulatory requirements will not change or past non-compliance with environmental laws will not be discovered on the Company’s properties.
Potential Decommissioning Obligations on Sold Properties
In 2013, Apache sold its Gulf of Mexico (GOM) Shelf operations and properties and its GOM operating subsidiary, GOM Shelf LLC (GOM Shelf) to Fieldwood Energy LLC (Fieldwood). Under the terms of the purchase agreement, Apache received cash consideration of $3.75 billion and Fieldwood assumed the obligation to decommission the properties held by GOM Shelf and the properties acquired from Apache and its other subsidiaries (collectively, the Legacy GOM Assets). In respect of such abandonment obligations, Fieldwood posted letters of credit in favor of Apache (Letters of Credit) and established trust accounts (Trust A and Trust B) of which Apache was a beneficiary and which were funded by two net profits interests (NPIs) depending on future oil prices. On February 14, 2018, Fieldwood filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In connection with the 2018 bankruptcy, Fieldwood confirmed a plan under which Apache agreed, inter alia, to (i) accept bonds in exchange for certain of the Letters of Credit and (ii) amend the Trust A trust agreement and one of the NPIs to consolidate the trusts into a single Trust (Trust A) funded by both remaining NPIs. Currently, Apache holds two bonds (Bonds) and five Letters of Credit to secure Fieldwood’s asset retirement obligations on the Legacy GOM Assets as and when Apache is required to perform or pay for decommissioning any Legacy GOM Asset over the remaining life of the Legacy GOM Assets.
On August 3, 2020, Fieldwood again filed for protection under Chapter 11 of the U.S. Bankruptcy Code. On June 25, 2021, the United States Bankruptcy Court for the Southern District of Texas (Houston Division) entered an order confirming Fieldwood’s bankruptcy plan. On August 27, 2021, Fieldwood’s bankruptcy plan became effective. Pursuant to the plan, the Legacy GOM Assets were separated into a standalone company, which was subsequently merged into GOM Shelf. Under GOM Shelf’s limited liability company agreement, the proceeds of production of the Legacy GOM Assets will be used to fund decommissioning of Legacy GOM Assets.
By letter dated April 5, 2022, replacing two prior letters dated September 8, 2021 and February 22, 2022, respectively, GOM Shelf notified the Bureau of Safety and Environmental Enforcement (BSEE) that it was unable to fund the decommissioning obligations that it is currently obligated to perform on certain of the Legacy GOM Assets. As a result, Apache and other current and former owners in these assets have received orders from BSEE to decommission certain of the Legacy GOM Assets included in GOM Shelf’s notification to BSEE. Apache expects to receive such orders on the other Legacy GOM Assets included in GOM Shelf’s notification letter. Further, Apache anticipates that GOM Shelf may send additional such notices to BSEE in the future and that it may receive additional orders from BSEE requiring it to decommission other Legacy GOM Assets.
If Apache incurs costs to decommission any Legacy GOM Asset and GOM Shelf does not reimburse Apache for such costs, then Apache expects to obtain reimbursement from Trust A, the Bonds, and the Letters of Credit until such funds and securities are fully utilized. In addition, after such sources have been exhausted, Apache has agreed to provide a standby loan to GOM Shelf of up to $400 million to perform decommissioning (Standby Loan Agreement), with such standby loan secured by a first and prior lien on the Legacy GOM Assets.
If the combination of GOM Shelf’s net cash flow from its producing properties, the Trust A funds, the Bonds, and the remaining Letters of Credit are insufficient to fully fund decommissioning of any Legacy GOM Assets that Apache may be ordered by BSEE to perform, or if GOM Shelf’s net cash flow from its remaining producing properties after the Trust A funds, Bonds, and Letters of Credit are exhausted is insufficient to repay any loans made by Apache under the Standby Loan Agreement, then Apache may be forced to effectively use its available cash to fund the deficit.
As of June 30, 2022, Apache estimates that its potential liability to fund decommissioning of Legacy GOM Assets it may be ordered to perform ranges from $1.2 billion to $1.4 billion on an undiscounted basis. Management does not believe any specific estimate within this range is a better estimate than any other. Accordingly, the Company has recorded a contingent liability of $1.2 billion as of June 30, 2022, representing the estimated costs of decommissioning it may be required to perform on Legacy GOM Assets. Of the total liability recorded, $825 million is reflected under the caption “Decommissioning contingency for sold Gulf of Mexico properties,” and $350 million is reflected under “Other current liabilities” in the Company’s consolidated balance sheet. The Company has also recorded a $733 million asset, which represents the amount the Company expects to be reimbursed from the Trust A funds, the Bonds, and the Letters of Credit for decommissioning it may be required to perform on Legacy GOM Assets. Of the total asset recorded, $383 million is reflected under the caption “Decommissioning security for sold Gulf of Mexico properties,” and $350 million is reflected under “Other current assets.” Changes in significant assumptions impacting Apache’s estimated liability, including expected decommissioning rig spread rates, lift boat rates, and planned abandonment logistics could result in a liability in excess of the amount accrued. In addition, significant changes in the market price of oil, gas, and NGLs could further impact Apache’s estimate of its contingent liability to decommission Legacy GOM Assets.
13. REDEEMABLE NONCONTROLLING INTEREST — ALTUS
Preferred Units Issuance
On June 12, 2019, Altus Midstream LP issued and sold Preferred Units for an aggregate issue price of $625 million in a private offering exempt from the registration requirements of the Securities Act (the Closing). Altus Midstream LP received approximately $611 million in cash proceeds from the sale after deducting transaction costs and discounts to certain purchasers.
Classification
Prior to the deconsolidation of Altus on February 22, 2022, at December 31, 2021, the carrying amount of the Preferred Units was recorded as “Redeemable Noncontrolling Interest — Altus Preferred Unit Limited Partners” classified as temporary equity on the Company’s consolidated balance sheet based on the terms of the Preferred Units, including the redemption rights with respect thereto.
Measurement
Altus applied a two-step approach to subsequent measurement of the redeemable noncontrolling interest related to the Preferred Units by first allocating a portion of the net income of Altus Midstream LP in accordance with the terms of the partnership agreement. An additional adjustment to the carrying value of the Preferred Unit redeemable noncontrolling interest at each period end was recorded, if applicable. The amount of such adjustment was determined based upon the accreted value method to reflect the passage of time until the Preferred Units were exchangeable at the option of the holder. Pursuant to this method, the net transaction price was accreted using the effective interest method to the Redemption Price calculated at the seventh anniversary of the Closing. The total adjustment was limited to an amount such that the carrying amount of the Preferred Unit redeemable noncontrolling interest at each period end was equal to the greater of (a) the sum of (i) the carrying amount of the Preferred Units, plus (ii) the fair value of the embedded derivative liability and (b) the accreted value of the net transaction price.
Activity related to the Preferred Units is as follows:
| | | | | | | | | | | | | | |
| | Units
Outstanding | | Financial Position |
| | (In millions, except unit data) |
| Redeemable noncontrolling interest — Preferred Units at: December 31, 2020 | | 660,694 | | | $ | 608 | |
| Cash distributions to Altus Preferred Unit limited partners | | — | | | (46) | |
| Distributions payable to Altus Preferred Unit limited partners | | — | | | (12) | |
| Allocation of Altus Midstream LP net income | | N/A | | 80 | |
| Accreted value adjustment | | N/A | | 82 | |
| Redeemable noncontrolling interest — Preferred Units at: December 31, 2021 | | 660,694 | | | 712 | |
| | | | |
| | | | |
| | | | |
| Allocation of Altus Midstream LP net income | | N/A | | 12 | |
Accreted value adjustment(1) | | N/A | | (82) | |
| Redeemable noncontrolling interest — Preferred Units at: February 22, 2022 | | 660,694 | | | 642 | |
| Preferred Units embedded derivative | | | | 89 | |
| Deconsolidation of Altus | | | | (731) | |
| | | | $ | — | |
(1) Includes the reversal of previously recorded accreted value adjustments of $53 million due to the deconsolidation of Altus.
N/A - not applicable.
14. CAPITAL STOCK AND EQUITY
Upon consummation of the Holding Company Reorganization, each outstanding share of Apache common stock automatically converted into a share of APA common stock on a one-for-one basis. As a result, each stockholder of Apache now owns the same number of shares of APA common stock that such stockholder owned of Apache common stock immediately prior to the Holding Company Reorganization. As a result of the Holding Company Reorganization and subsequent activity, Apache recorded various intercompany activities during the first quarter ended March 31, 2021 as capital transactions, which are reflected in Apache’s Statement of Consolidated Changes in Equity (Deficit) and Noncontrolling Interests. Refer to Note 2—Transactions with Parent Affiliate for more detail. Additionally, in connection with the Holding Company Reorganization, Apache transferred to APA, and APA assumed, sponsorship of all of Apache’s stock plans along with all of Apache’s rights and obligations under each plan. Subsequent to the Holding Company Reorganization, stock-based compensation associated with APA equity awards granted and outstanding to Apache employees are reflected as capital contributions from APA to Apache.
Net Income (Loss) per Common Share
Net income (loss) per share for Apache is no longer required, as its shares are not publicly traded, and Apache is now a direct, wholly owned subsidiary of APA.
Distributions to APA Corporation and Common Stock Dividends
During the six months ended June 30, 2022 and 2021, the Company paid $733 million and $10 million, respectively, in capital distributions to its parent, APA, which is included as “Distributions to APA Corporation” on the Company’s statement of consolidated cash flows. During the quarter ended March 31, 2021, prior to completion of the Holding Company Reorganization, the Company paid $9 million in dividends on its common stock.
15. BUSINESS SEGMENT INFORMATION
As of June 30, 2022, the Company is engaged in exploration and production (Upstream) activities across three operating segments: Egypt, North Sea, and the U.S. The Company’s Upstream business explores for, develops, and produces crude oil, natural gas, and natural gas liquids. Prior to the deconsolidation of Altus on February 22, 2022, the Company’s Midstream business was operated by Altus Midstream Company, which owned, developed, and operated a midstream energy asset network in the Permian Basin of West Texas. Financial information for each segment is presented below:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Egypt(1) | | North Sea | | U.S. | | Altus Midstream | | Intersegment Eliminations & Other | | Total(4) |
| | Upstream | | | |
| | | | | | | | | | | | |
For the Quarter Ended June 30, 2022 | | (In millions) |
| Revenues: | | | | | | | | | | | | |
| Oil revenues | | $ | 902 | | | $ | 307 | | | $ | 654 | | | $ | — | | | $ | — | | | $ | 1,863 | |
| Natural gas revenues | | 88 | | | 64 | | | 281 | | | — | | | — | | | 433 | |
| Natural gas liquids revenues | | 3 | | | 12 | | | 214 | | | — | | | — | | | 229 | |
| Oil, natural gas, and natural gas liquids production revenues | | 993 | | | 383 | | | 1,149 | | | — | | | — | | | 2,525 | |
| Purchased oil and gas sales | | — | | | — | | | 522 | | | — | | | — | | | 522 | |
| | | | | | | | | | | | |
| | 993 | | | 383 | | | 1,671 | | | — | | | — | | | 3,047 | |
| Operating Expenses: | | | | | | | | | | | | |
| Lease operating expenses | | 131 | | | 118 | | | 110 | | | — | | | — | | | 359 | |
| Gathering, processing, and transmission | | 5 | | | 12 | | | 77 | | | — | | | — | | | 94 | |
| Purchased oil and gas costs | | — | | | — | | | 528 | | | — | | | — | | | 528 | |
| Taxes other than income | | — | | | — | | | 78 | | | — | | | — | | | 78 | |
| Exploration | | 12 | | | 2 | | | 1 | | | — | | | — | | | 15 | |
| Depreciation, depletion, and amortization | | 91 | | | 54 | | | 133 | | | — | | | — | | | 278 | |
| Asset retirement obligation accretion | | — | | | 20 | | | 9 | | | — | | | — | | | 29 | |
| | | | | | | | | | | | |
| | 239 | | | 206 | | | 936 | | | — | | | — | | | 1,381 | |
Operating Income (Loss)(2) | | $ | 754 | | | $ | 177 | | | $ | 735 | | | $ | — | | | $ | — | | | 1,666 | |
| | | | | | | | | | | | |
| Other Income (Expense): | | | | | | | | | | | | |
| Derivative instrument losses, net | | | | | | | | | | | | (32) | |
| | | | | | | | | | | | |
| Loss on divestitures, net | | | | | | | | | | | | (27) | |
| Other, net | | | | | | | | | | | | 64 | |
| General and administrative | | | | | | | | | | | | (83) | |
| Transaction, reorganization, and separation | | | | | | | | | | | | (3) | |
| Financing costs, net | | | | | | | | | | | | (62) | |
| Income Before Income Taxes | | | | | | | | | | | | $ | 1,523 | |
| | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Egypt(1) | | North Sea | | U.S. | | Altus Midstream | | Intersegment Eliminations & Other | | Total(4) |
| | Upstream | | | |
| | | | | | | | | | | | |
For the Six Months Ended June 30, 2022 | | (In millions) |
| Revenues: | | | | | | | | | | | | |
| Oil revenues | | $ | 1,692 | | | $ | 635 | | | $ | 1,253 | | | $ | — | | | $ | — | | | $ | 3,580 | |
| Natural gas revenues | | 186 | | | 163 | | | 464 | | | — | | | — | | | 813 | |
| Natural gas liquids revenues | | 6 | | | 28 | | | 421 | | | — | | | (3) | | | 452 | |
| Oil, natural gas, and natural gas liquids production revenues | | 1,884 | | | 826 | | | 2,138 | | | — | | | (3) | | | 4,845 | |
| Purchased oil and gas sales | | — | | | — | | | 866 | | | 5 | | | — | | | 871 | |
| Midstream service affiliate revenues | | — | | | — | | | — | | | 16 | | | (16) | | | — | |
| | 1,884 | | | 826 | | | 3,004 | | | 21 | | | (19) | | | 5,716 | |
| Operating Expenses: | | | | | | | | | | | | |
| Lease operating expenses | | 262 | | | 214 | | | 228 | | | — | | | (1) | | | 703 | |
| Gathering, processing, and transmission | | 10 | | | 24 | | | 154 | | | 5 | | | (18) | | | 175 | |
| Purchased oil and gas costs | | — | | | — | | | 879 | | | — | | | — | | | 879 | |
| Taxes other than income | | — | | | — | | | 145 | | | 3 | | | — | | | 148 | |
| Exploration | | 27 | | | 7 | | | 5 | | | — | | | 1 | | | 40 | |
| Depreciation, depletion, and amortization | | 188 | | | 116 | | | 263 | | | 2 | | | — | | | 569 | |
| Asset retirement obligation accretion | | — | | | 40 | | | 17 | | | 1 | | | — | | | 58 | |
| | | | | | | | | | | | |
| | 487 | | | 401 | | | 1,691 | | | 11 | | | (18) | | | 2,572 | |
Operating Income (Loss)(2) | | $ | 1,397 | | | $ | 425 | | | $ | 1,313 | | | $ | 10 | | | $ | (1) | | | 3,144 | |
| | | | | | | | | | | | |
| Other Income (Expense): | | | | | | | | | | | | |
| Derivative instrument losses, net | | | | | | | | | | | | (94) | |
| | | | | | | | | | | | |
| Gain on divestitures, net | | | | | | | | | | | | 1,149 | |
| Other, net | | | | | | | | | | | | 109 | |
| General and administrative | | | | | | | | | | | | (234) | |
| Transaction, reorganization, and separation | | | | | | | | | | | | (17) | |
| Financing costs, net | | | | | | | | | | | | (202) | |
| Income Before Income Taxes | | | | | | | | | | | | $ | 3,855 | |
| | | | | | | | | | | | |
Total Assets(3) | | $ | 3,107 | | | $ | 2,103 | | | $ | 8,629 | | | $ | — | | | $ | — | | | $ | 13,839 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Egypt(1) | | North Sea | | U.S. | | Altus Midstream | | Intersegment Eliminations & Other | | Total(4) |
| | Upstream | | | |
| | | | | | | | | | | | |
For the Quarter Ended June 30, 2021 | | (In millions) |
| Revenues: | | | | | | | | | | | | |
| Oil revenues | | $ | 432 | | | $ | 216 | | | $ | 493 | | | $ | — | | | $ | — | | | $ | 1,141 | |
| Natural gas revenues | | 65 | | | 27 | | | 134 | | | — | | | — | | | 226 | |
| Natural gas liquids revenues | | 2 | | | 4 | | | 141 | | | — | | | — | | | 147 | |
| Oil, natural gas, and natural gas liquids production revenues | | 499 | | | 247 | | | 768 | | | — | | | — | | | 1,514 | |
| Purchased oil and gas sales | | — | | | — | | | 239 | | | 3 | | | — | | | 242 | |
| Midstream service revenues | | — | | | — | | | — | | | 32 | | | (32) | | | — | |
| | 499 | | | 247 | | | 1,007 | | | 35 | | | (32) | | | 1,756 | |
| Operating Expenses: | | | | | | | | | | | | |
| Lease operating expenses | | 114 | | | 98 | | | 99 | | | — | | | — | | | 311 | |
| Gathering, processing, and transmission | | 3 | | | 8 | | | 74 | | | 8 | | | (32) | | | 61 | |
| Purchased oil and gas costs | | — | | | — | | | 259 | | | 3 | | | — | | | 262 | |
| Taxes other than income | | — | | | — | | | 47 | | | 4 | | | — | | | 51 | |
| Exploration | | 14 | | | 3 | | | 2 | | | — | | | — | | | 19 | |
| Depreciation, depletion, and amortization | | 137 | | | 63 | | | 148 | | | 3 | | | — | | | 351 | |
| Asset retirement obligation accretion | | — | | | 20 | | | 7 | | | 1 | | | — | | | 28 | |
| | | | | | | | | | | | |
| | 268 | | | 192 | | | 636 | | | 19 | | | (32) | | | 1,083 | |
Operating Income (Loss)(2) | | $ | 231 | | | $ | 55 | | | $ | 371 | | | $ | 16 | | | $ | — | | | 673 | |
| | | | | | | | | | | | |
| Other Income (Expense): | | | | | | | | | | | | |
| Derivative instrument losses, net | | | | | | | | | | | | (113) | |
| Gain on divestitures, net | | | | | | | | | | | | 65 | |
| Other, net | | | | | | | | | | | | 74 | |
| General and administrative | | | | | | | | | | | | (79) | |
| Transaction, reorganization, and separation | | | | | | | | | | | | (4) | |
| Financing costs, net | | | | | | | | | | | | (94) | |
| Income Before Income Taxes | | | | | | | | | | | | $ | 522 | |
| | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Egypt(1) | | North Sea | | U.S. | | Altus Midstream | | Intersegment Eliminations & Other | | Total(4) |
| | Upstream | | | |
| | | | | | | | | | | | |
For the Six Months Ended June 30, 2021 | | (In millions) |
| Revenues: | | | | | | | | | | | | |
| Oil revenues | | $ | 834 | | | $ | 457 | | | $ | 841 | | | $ | — | | | $ | — | | | $ | 2,132 | |
| Natural gas revenues | | 135 | | | 58 | | | 345 | | | — | | | — | | | 538 | |
| Natural gas liquids revenues | | 4 | | | 10 | | | 261 | | | — | | | — | | | 275 | |
| Oil, natural gas, and natural gas liquids production revenues | | 973 | | | 525 | | | 1,447 | | | — | | | — | | | 2,945 | |
| Purchased oil and gas sales | | — | | | — | | | 676 | | | 6 | | | — | | | 682 | |
| Midstream service affiliate revenues | | — | | | — | | | — | | | 64 | | | (64) | | | — | |
| | 973 | | | 525 | | | 2,123 | | | 70 | | | (64) | | | 3,627 | |
| Operating Expenses: | | | | | | | | | | | | |
| Lease operating expenses | | 218 | | | 173 | | | 185 | | | — | | | (1) | | | 575 | |
| Gathering, processing, and transmission | | 4 | | | 20 | | | 143 | | | 15 | | | (63) | | | 119 | |
| Purchased oil and gas costs | | — | | | — | | | 751 | | | 5 | | | — | | | 756 | |
| Taxes other than income | | — | | | — | | | 87 | | | 8 | | | — | | | 95 | |
| Exploration | | 22 | | | 23 | | | 18 | | | — | | | 2 | | | 65 | |
| Depreciation, depletion, and amortization | | 267 | | | 147 | | | 273 | | | 6 | | | — | | | 693 | |
| Asset retirement obligation accretion | | — | | | 39 | | | 15 | | | 2 | | | — | | | 56 | |
| | | | | | | | | | | | |
| | 511 | | | 402 | | | 1,472 | | | 36 | | | (62) | | | 2,359 | |
Operating Income (Loss)(2) | | $ | 462 | | | $ | 123 | | | $ | 651 | | | $ | 34 | | | $ | (2) | | | 1,268 | |
| | | | | | | | | | | | |
| Other Income (Expense): | | | | | | | | | | | | |
| Derivative instrument gains, net | | | | | | | | | | | | 45 | |
| Gain on divestitures, net | | | | | | | | | | | | 67 | |
| Other, net | | | | | | | | | | | | 135 | |
| General and administrative | | | | | | | | | | | | (162) | |
| Transaction, reorganization, and separation | | | | | | | | | | | | (4) | |
| Financing costs, net | | | | | | | | | | | | (201) | |
| Income Before Income Taxes | | | | | | | | | | | | $ | 1,148 | |
| | | | | | | | | | | | |
Total Assets(3) | | $ | 3,116 | | | $ | 2,127 | | | $ | 7,305 | | | $ | 1,839 | | | $ | 1 | | | $ | 14,388 | |
(1) Includes revenue from non-customers for the quarters and six months ended June 30, 2022 and 2021 of:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | For the Quarter Ended June 30, | | For the Six Months Ended June 30, |
| | | 2022 | | 2021 | | 2022 | | 2021 |
| | | | | | | | |
| | (In millions) | | | | |
| Oil | | $ | 302 | | | $ | 97 | | | $ | 552 | | | $ | 190 | |
| Natural gas | | 30 | | | 10 | | | 61 | | | 22 | |
| Natural gas liquids | | 1 | | | — | | | 2 | | | 1 | |
(2)Operating income of U.S. and Egypt includes leasehold impairments of $1 million and $1 million, respectively, for the second quarter of 2022. Operating income of U.S. and Egypt includes leasehold impairments of $4 million and $2 million, respectively, for the first six months of 2022. Operating income of U.S. and Egypt includes leasehold and other asset impairments of $1 million and $2 million, respectively, for the second quarter of 2021. Operating income of U.S. and Egypt includes leasehold impairments of $17 million and $4 million, respectively, for the first six months of 2021.
(3)Intercompany balances are excluded from total assets.
(4)Includes noncontrolling interests of Sinopec, Altus prior to deconsolidation, and APA.