filings.toolsItem 1. Financial Statements (unaudited)
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Item 1. Financial Statements (unaudited)
| Consolidated Condensed Balance Sheets | Occidental Petroleum Corporation and Subsidiaries |
| millions | June 30, 2026 | December 31, 2025 | ||||||
| ASSETS | ||||||||
| Cash and cash equivalents | $ | 4,150 | $ | 1,968 | ||||
| Trade receivables, net of reserves | 3,142 | 2,575 | ||||||
| Joint interest receivables | 902 | 684 | ||||||
| Inventories | 2,185 | 1,823 | ||||||
| Other current assets | 753 | 601 | ||||||
| Current assets held for sale | — | 1,176 | ||||||
| Total current assets | 11,132 | 8,827 | ||||||
| Property, plant and equipment, gross | 134,409 | 137,753 | ||||||
| Accumulated depreciation, depletion and amortization | (71,809) | (74,110) | ||||||
| Total property, plant and equipment, net | 62,600 | 63,643 | ||||||
| Operating lease assets | 829 | 908 | ||||||
| Investments in unconsolidated entities | 2,569 | 2,475 | ||||||
| Non-current assets held for sale | — | 5,344 | ||||||
| Other long-term assets | 3,228 | 2,989 | ||||||
| Total non-current assets | 6,626 | 11,716 | ||||||
| TOTAL ASSETS | $ | 80,358 | $ | 84,186 |
| LIABILITIES | ||||||||
| Current maturities of long-term debt | $ | 203 | $ | 1,773 | ||||
| Accounts payable | 3,572 | 3,285 | ||||||
| Accrued liabilities | 4,117 | 3,592 | ||||||
| Liabilities held for sale | — | 778 | ||||||
| Total current liabilities | 7,892 | 9,428 | ||||||
| Long-term debt, net | 13,540 | 20,623 | ||||||
| Deferred income taxes, net | 5,671 | 5,636 | ||||||
| Asset retirement obligations | 3,656 | 4,172 | ||||||
| Non-current liabilities held for sale | — | 418 | ||||||
| Other deferred credits and liabilities | 7,218 | 7,311 | ||||||
| Total deferred credits and other liabilities | 16,545 | 17,537 | ||||||
| EQUITY | ||||||||
| Preferred stock, at $1.00 per share par value, issued shares: 2026 — 84,897 and 2025 —84,897 | 8,287 | 8,287 | ||||||
| Common stock, at $0.20 per share par value, authorized shares: 1.5 billion, issued shares: 2026 — 1,230,039,058 and 2025 — 1,214,337,600 | 246 | 243 | ||||||
| Treasury stock: 2026 — 230,330,507 shares and 2025 — 228,311,184 shares | (15,714) | (15,597) | ||||||
| Additional paid-in capital | 21,386 | 21,008 | ||||||
| Retained earnings | 27,350 | 21,891 | ||||||
| Accumulated other comprehensive income | 191 | 202 | ||||||
| Total stockholders' equity | 41,746 | 36,034 | ||||||
| Noncontrolling interest | 635 | 564 | ||||||
| Total equity | 42,381 | 36,598 | ||||||
| TOTAL LIABILITIES AND EQUITY | $ | 80,358 | $ | 84,186 |
The accompanying notes are an integral part of these Consolidated Condensed Financial Statements.
| Consolidated Condensed Statements of Operations | Occidental Petroleum Corporation and Subsidiaries |
| Three months ended June 30, | Six months ended June 30, | |||||||||||||
| millions, except per-share amounts | 2026 | 2025 | 2026 | 2025 | ||||||||||
| REVENUES AND OTHER INCOME | ||||||||||||||
| Net sales | $ | 8,065 | $ | 5,258 | $ | 13,295 | $ | 10,962 | ||||||
| Interest, dividends and other income | 82 | 48 | 163 | 101 | ||||||||||
| Gains (losses) on sales of assets and other, net | 180 | (5) | (22) | (24) | ||||||||||
| Total | 8,327 | 5,301 | 13,436 | 11,039 | ||||||||||
| COSTS AND OTHER DEDUCTIONS | ||||||||||||||
| Oil and gas lease operating expense | 1,117 | 1,135 | 2,235 | 2,352 | ||||||||||
| Transportation and gathering expense | 463 | 448 | 884 | 900 | ||||||||||
| General and administrative expense | 262 | 257 | 507 | 498 | ||||||||||
| Other operating and non-operating expense | 332 | 445 | 688 | 771 | ||||||||||
| Taxes other than on income | 342 | 269 | 601 | 533 | ||||||||||
| Depreciation, depletion and amortization | 1,847 | 1,823 | 3,641 | 3,627 | ||||||||||
| Asset impairments and other charges | 38 | — | 158 | — | ||||||||||
| Acquisition-related costs | — | 6 | — | 12 | ||||||||||
| Exploration expense | 37 | 83 | 147 | 138 | ||||||||||
| Interest and debt expense, net | 108 | 271 | 540 | 581 | ||||||||||
| Total | 4,546 | 4,737 | 9,401 | 9,412 | ||||||||||
| Income before income taxes and other items | 3,781 | 564 | 4,035 | 1,627 | ||||||||||
| OTHER ITEMS | ||||||||||||||
| Income (loss) from equity investments and other | 134 | (4) | 270 | 110 | ||||||||||
| Total | 134 | (4) | 270 | 110 | ||||||||||
| Income before income taxes | 3,915 | 560 | 4,305 | 1,737 | ||||||||||
| Income tax expense | (915) | (222) | (1,069) | (569) | ||||||||||
| Income from continuing operations | 3,000 | 338 | 3,236 | 1,168 | ||||||||||
| Discontinued operations, net of tax | (4) | 130 | 3,119 | 245 | ||||||||||
| NET INCOME | 2,996 | 468 | 6,355 | 1,413 | ||||||||||
| Less: Net income attributable to noncontrolling interest | (19) | (10) | (33) | (19) | ||||||||||
| Less: Preferred stock dividends | (170) | (170) | (340) | (340) | ||||||||||
| NET INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS | $ | 2,807 | $ | 288 | $ | 5,982 | $ | 1,054 | ||||||
| PER COMMON SHARE | ||||||||||||||
| Income from continuing operations—basic | $ | 2.80 | $ | 0.14 | $ | 2.86 | $ | 0.80 | ||||||
| Discontinued operations—basic | — | 0.13 | 3.12 | 0.26 | ||||||||||
| Net income attributable to common stockholders—basic | $ | 2.80 | $ | 0.27 | $ | 5.98 | $ | 1.06 | ||||||
| Income from continuing operations—diluted | $ | 2.76 | $ | 0.13 | $ | 2.82 | $ | 0.78 | ||||||
| Discontinued operations—diluted | (0.01) | 0.13 | 3.07 | 0.25 | ||||||||||
| Net income attributable to common stockholders—diluted | $ | 2.75 | $ | 0.26 | $ | 5.89 | $ | 1.03 | ||||||
| The accompanying notes are an integral part of these Consolidated Condensed Financial Statements. |
| Consolidated Condensed Statements of Comprehensive Income | Occidental Petroleum Corporation and Subsidiaries |
| Three months ended June 30, | Six months ended June 30, | |||||||||||||
| millions | 2026 | 2025 | 2026 | 2025 | ||||||||||
| Net income | $ | 2,996 | $ | 468 | $ | 6,355 | $ | 1,413 | ||||||
| Other comprehensive income (loss) items: | ||||||||||||||
| Gains (losses) on derivatives | — | (8) | 3 | (11) | ||||||||||
| Pension and postretirement losses | (3) | (2) | (19) | (5) | ||||||||||
| Other | — | 4 | 5 | 1 | ||||||||||
| Other comprehensive loss, net of tax | (3) | (6) | (11) | (15) | ||||||||||
| Comprehensive income | 2,993 | 462 | 6,344 | 1,398 | ||||||||||
| Comprehensive income attributable to noncontrolling interest | (19) | (10) | (33) | (19) | ||||||||||
| Comprehensive income attributable to preferred and common stockholders | $ | 2,974 | $ | 452 | $ | 6,311 | $ | 1,379 |
The accompanying notes are an integral part of these Consolidated Condensed Financial Statements.
| Consolidated Condensed Statements of Equity | Occidental Petroleum Corporation and Subsidiaries |
| Equity Attributable to Common Stock | ||||||||||||||||||||||||||
| millions, except per-share amounts | Preferred Stock | Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Income (Loss) | Noncontrolling interest | Total Equity | ||||||||||||||||||
| Balance as of March 31, 2025 | $ | 8,287 | $ | 234 | $ | (15,597) | $ | 19,892 | $ | 21,726 | $ | 170 | $ | 393 | $ | 35,105 | ||||||||||
| Net income | — | — | — | — | 458 | — | 10 | 468 | ||||||||||||||||||
| Other comprehensive loss, net of tax | — | — | — | — | — | (6) | — | (6) | ||||||||||||||||||
| Dividends on common stock, $0.24 per share | — | — | — | — | (238) | — | — | (238) | ||||||||||||||||||
| Dividends on preferred stock, $2,000 per share | — | — | — | — | (170) | — | — | (170) | ||||||||||||||||||
| Shareholder warrants exercised | — | 9 | — | 884 | — | — | — | 893 | ||||||||||||||||||
| Issuance of common stock and other, net of cancellations | — | — | — | 73 | — | — | — | 73 | ||||||||||||||||||
| Noncontrolling interest contributions | — | — | — | — | — | — | 51 | 51 | ||||||||||||||||||
| Balance as of June 30, 2025 | $ | 8,287 | $ | 243 | $ | (15,597) | $ | 20,849 | $ | 21,776 | $ | 164 | $ | 454 | $ | 36,176 |
| Equity Attributable to Common Stock | ||||||||||||||||||||||||||
| millions, except per-share amounts | Preferred Stock | Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Income (Loss) | Noncontrolling interest | Total Equity | ||||||||||||||||||
| Balance as of March 31, 2026 | $ | 8,287 | $ | 244 | $ | (15,676) | $ | 21,077 | $ | 24,806 | $ | 194 | $ | 628 | $ | 39,560 | ||||||||||
| Net income | — | — | — | — | 2,977 | — | 19 | 2,996 | ||||||||||||||||||
| Other comprehensive loss, net of tax | — | — | — | — | — | (3) | — | (3) | ||||||||||||||||||
| Dividends on common stock, $0.26 per share | — | — | — | — | (263) | — | — | (263) | ||||||||||||||||||
| Dividends on preferred stock, $2,000 per share | — | — | — | — | (170) | — | — | (170) | ||||||||||||||||||
| Shareholder warrants exercised | — | 2 | — | 195 | — | — | — | 197 | ||||||||||||||||||
| Options exercised | — | — | — | 3 | — | — | — | 3 | ||||||||||||||||||
| Issuance of common stock and other, net of cancellations | — | — | — | 111 | — | — | — | 111 | ||||||||||||||||||
| Purchases of treasury stock | — | — | (38) | — | — | — | — | (38) | ||||||||||||||||||
| Noncontrolling interest distributions | — | — | — | — | — | — | (12) | (12) | ||||||||||||||||||
| Balance as of June 30, 2026 | $ | 8,287 | $ | 246 | $ | (15,714) | $ | 21,386 | $ | 27,350 | $ | 191 | $ | 635 | $ | 42,381 |
The accompanying notes are an integral part of these Consolidated Condensed Financial Statements.
| Consolidated Condensed Statements of Equity | Occidental Petroleum Corporation and Subsidiaries |
| Equity Attributable to Common Stock | ||||||||||||||||||||||||||
| millions, except per-share amounts | Preferred Stock | Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Income (Loss) | Noncontrolling interest | Total Equity | ||||||||||||||||||
| Balance as of December 31, 2024 | $ | 8,287 | $ | 233 | $ | (15,597) | $ | 19,868 | $ | 21,189 | $ | 179 | $ | 321 | $ | 34,480 | ||||||||||
| Net income | — | — | — | — | 1,394 | — | 19 | 1,413 | ||||||||||||||||||
| Other comprehensive loss, net of tax | — | — | — | — | — | (15) | — | (15) | ||||||||||||||||||
| Dividends on common stock, $0.48 per share | — | — | — | — | (467) | — | — | (467) | ||||||||||||||||||
| Dividends on preferred stock, $4,000 per share | — | — | — | — | (340) | — | — | (340) | ||||||||||||||||||
| Shareholder warrants exercised | — | 9 | — | 887 | — | — | — | 896 | ||||||||||||||||||
| Issuance of common stock and other, net of cancellations | — | 1 | — | 94 | — | — | — | 95 | ||||||||||||||||||
| Noncontrolling interest contributions | — | — | — | — | — | — | 114 | 114 | ||||||||||||||||||
| Balance as of June 30, 2025 | $ | 8,287 | $ | 243 | $ | (15,597) | $ | 20,849 | $ | 21,776 | $ | 164 | $ | 454 | $ | 36,176 |
| Equity Attributable to Common Stock | ||||||||||||||||||||||||||
| millions, except per-share amounts | Preferred Stock | Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Income (Loss) | Noncontrolling interest | Total Equity | ||||||||||||||||||
| Balance as of December 31, 2025 | $ | 8,287 | $ | 243 | $ | (15,597) | $ | 21,008 | $ | 21,891 | $ | 202 | $ | 564 | $ | 36,598 | ||||||||||
| Net income | — | — | — | — | 6,322 | — | 33 | 6,355 | ||||||||||||||||||
| Other comprehensive loss, net of tax | — | — | — | — | — | (11) | — | (11) | ||||||||||||||||||
| Dividends on common stock, $0.52 per share | — | — | — | — | (523) | — | — | (523) | ||||||||||||||||||
| Dividends on preferred stock, $4,000 per share | — | — | — | — | (340) | — | — | (340) | ||||||||||||||||||
| Shareholder warrants exercised | — | 3 | — | 273 | — | — | — | 276 | ||||||||||||||||||
| Options exercised | — | — | — | 9 | — | — | — | 9 | ||||||||||||||||||
| Issuance of common stock and other, net of cancellations | — | — | — | 96 | — | — | — | 96 | ||||||||||||||||||
| Purchases of treasury stock | — | — | (117) | — | — | — | — | (117) | ||||||||||||||||||
| Noncontrolling interest contributions, net | — | — | — | — | — | — | 38 | 38 | ||||||||||||||||||
| Balance as of June 30, 2026 | $ | 8,287 | $ | 246 | $ | (15,714) | $ | 21,386 | $ | 27,350 | $ | 191 | $ | 635 | $ | 42,381 |
The accompanying notes are an integral part of these Consolidated Condensed Financial Statements.
| Consolidated Condensed Statements of Cash Flows | Occidental Petroleum Corporation and Subsidiaries |
| Six months ended June 30, | ||||||||
| millions | 2026 | 2025 | ||||||
| CASH FLOW FROM OPERATING ACTIVITIES | ||||||||
| Net income | $ | 6,355 | $ | 1,413 | ||||
| Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||
| Discontinued operations, net | (3,119) | (245) | ||||||
| Depreciation, depletion and amortization of assets | 3,641 | 3,627 | ||||||
| Deferred income tax provision (benefit) | 757 | (137) | ||||||
| Asset impairments and other charges | 105 | — | ||||||
| Losses on sales of assets and other, net | 22 | 24 | ||||||
| Other noncash charges to income | 100 | 497 | ||||||
| Changes in operating assets and liabilities: | ||||||||
| (Increase) decrease in trade receivables | (566) | 121 | ||||||
| (Increase) decrease in inventories | (334) | 286 | ||||||
| (Increase) decrease in joint interest receivables and other current assets | (172) | 26 | ||||||
| Decrease in accounts payable and accrued liabilities | (314) | (658) | ||||||
| Increase (decrease) in current domestic and foreign income taxes | 3 | (193) | ||||||
| Operating cash flow from continuing operations | 6,478 | 4,761 | ||||||
| Operating cash flow from discontinued operations, net of taxes | (926) | 347 | ||||||
| Net cash provided by operating activities | 5,552 | 5,108 | ||||||
| CASH FLOW FROM INVESTING ACTIVITIES | ||||||||
| Capital expenditures | (3,143) | (3,387) | ||||||
| Change in capital accrual | (65) | 26 | ||||||
| Purchases of assets, businesses and equity investments, net | (94) | (108) | ||||||
| Proceeds from sales of assets, net | 71 | 1,450 | ||||||
| Equity investments and other, net | (164) | (149) | ||||||
| Investing cash flow from continuing operations | (3,395) | (2,168) | ||||||
| Investing cash flow from discontinued operations | 9,461 | (562) | ||||||
| Net cash provided (used) by investing activities | 6,066 | (2,730) | ||||||
| CASH FLOW FROM FINANCING ACTIVITIES | ||||||||
| Payments of debt | (8,695) | (2,280) | ||||||
| Cash dividends paid on common and preferred stock | (839) | (778) | ||||||
| Proceeds from issuance of common stock | 295 | 931 | ||||||
| Purchases of treasury stock | (117) | — | ||||||
| Contributions from noncontrolling interest, net | 38 | 114 | ||||||
| Other financing, net | (158) | (158) | ||||||
| Financing cash flow from continuing operations | (9,476) | (2,171) | ||||||
| Financing cash flow from discontinued operations | — | (4) | ||||||
| Net cash used by financing activities | (9,476) | (2,175) | ||||||
| Increase in cash, cash equivalents, restricted cash and restricted cash equivalents | 2,142 | 203 | ||||||
| Cash, cash equivalents, restricted cash and restricted cash equivalents — beginning of period | 2,046 | 2,157 | ||||||
| Cash, cash equivalents, restricted cash and restricted cash equivalents — end of period | $ | 4,188 | $ | 2,360 | ||||
| The accompanying notes are an integral part of these Consolidated Condensed Financial Statements. |
| Notes to Consolidated Condensed Financial Statements | Occidental Petroleum Corporation and Subsidiaries |
| NOTE 1 - GENERAL |
NATURE OF OPERATIONS
The Company conducts its operations through various subsidiaries and affiliates. The Company has made its disclosures in accordance with United States generally accepted accounting principles as they apply to interim reporting and has condensed or omitted, as permitted by the rules and regulations of the SEC, certain information and disclosures normally included in Consolidated Financial Statements and the notes thereto. These unaudited Consolidated Condensed Financial Statements should be read in conjunction with the audited Consolidated Financial Statements and the notes thereto in the 2025 Form 10-K.
In the opinion of the Company's management, the accompanying unaudited Consolidated Condensed Financial Statements in this report reflect all adjustments (consisting of normal recurring adjustments) that are necessary to fairly present the Company's results of operations and cash flows for the six months ended June 30, 2026 and 2025 and the Company's financial position as of June 30, 2026 and December 31, 2025. The income and cash flows for the periods ended June 30, 2026 and 2025 are not necessarily indicative of the income or cash flows to be expected for the full year.
WES INVESTMENT
WES is a publicly traded limited partnership with its limited partner units traded on the NYSE under the ticker symbol "WES." As of June 30, 2026, the Company owned all of the 2.1% non-voting general partner interest, 36.4% of the WES limited partner units, and a 1.9% non-voting limited partner interest in WES Operating, a subsidiary of WES. In February 2026, in connection with the amendment of certain commercial agreements, the Company transferred 15.3 million units to WES, and recorded charges of $105 million. In June 2026, WES acquired Brazos Delaware II, LLC with a mix of equity and cash, and the Company recognized a gain of $220 million from its pro-rata ownership reduction in WES. As of June 30, 2026, the Company's combined share of net income from WES and its subsidiaries was 39.0%.
DISCONTINUED OPERATIONS
The OxyChem Transaction closed on January 2, 2026 for an adjusted sales price of $9.5 billion, subject to additional post-closing adjustments. In connection with the transaction, the Company retained environmental liabilities relating to legacy sites. Furthermore, there are post-closing indemnification obligations for (i) such legacy environmental liabilities and (ii) pre-closing liabilities of OxyChem, including pre-closing environmental liabilities, in each case subject to certain limitations and procedures, and Occidental entered into a guaranty in favor of Berkshire Hathaway to guarantee these indemnification obligations.
As a result of our agreement to sell OxyChem, the following changes in our basis of presentation have occurred:
■In accordance with ASC 205, Discontinued Operations, intersegment sales from our oil and gas and midstream and marketing segments to the chemical segment are no longer eliminated as intercompany transactions. All periods presented have been retrospectively adjusted to reflect this change.
■Beginning October 1, 2025, in accordance with ASC 360, Property, Plant, and Equipment (PP&E), depreciation and amortization were no longer recorded for the chemical segment's PP&E and right of use lease assets.
Unless otherwise indicated, information presented in the Notes to Consolidated Financial Statements relates only to the Company's continuing operations. Additional information related to discontinued operations is included in Note 4 - Acquisitions, Divestitures and Other Transactions and in some instances, where appropriate, is included as a separate disclosure within the individual Notes to Consolidated Financial Statements.
NONCONTROLLING INTEREST
Together with BlackRock, the Company is a joint venture partner in the development of the world's first commercial-scale direct air capture facility. As the primary beneficiary, the Company consolidates the joint venture, which is classified as a Variable Interest Entity. BlackRock's investment is accounted for as an NCI. As of June 30, 2026, BlackRock has invested the entirety of its total commitment of $550 million. In addition, the Company has entered into agreements with the joint venture related to project management, operations and maintenance and carbon removal offtake. The Company may incur additional payments if certain construction and operational thresholds are not met.
The Company may call the NCI on June 30, 2035 or earlier if the plant does not achieve commercial operations or ceases and permanently discontinues operations. Dividends from the joint venture will be distributed preferentially to the NCI up to a return threshold, then preferentially to the Company thereafter. The NCI receives preferential distributions in liquidation.
The Company has determined that the appropriate methodology for attributing income and loss from the joint venture is the Hypothetical Liquidation at Book Value method. As of June 30, 2026, the joint venture's assets were comprised of $1.3 billion construction in progress. Noncontrolling interest as of June 30, 2026 was $635 million. In the six months ended June 30, 2026, contributions of $50 million from BlackRock were netted with $12 million in distributions to BlackRock.
CASH EQUIVALENTS AND RESTRICTED CASH EQUIVALENTS
The Company considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents or restricted cash equivalents. The cash equivalents and restricted cash equivalents balances for the periods presented include investments in government money market funds in which the carrying value approximates fair value.
The following table provides a reconciliation of cash, cash equivalents, restricted cash and restricted cash equivalents as reported in the Consolidated Condensed Statements of Cash Flows as of:
| millions | June 30, 2026 | June 30, 2025 | ||||||
| Cash and cash equivalents | $ | 4,150 | $ | 2,314 | ||||
| Cash and cash equivalents included in assets held for sale | — | 12 | ||||||
| Restricted cash and restricted cash equivalents included in other current assets | 19 | 16 | ||||||
| Restricted cash and restricted cash equivalents included in other long-term assets | 19 | 18 | ||||||
| Cash, cash equivalents, restricted cash and restricted cash equivalents | $ | 4,188 | $ | 2,360 |
RECEIVABLES AND OTHER CURRENT ASSETS
Trade receivables, net of reserves, were $3.1 billion and $2.6 billion as of June 30, 2026 and December 31, 2025, respectively, and represent rights to payment for which the Company had satisfied its obligations under a contract with a customer and its right to payment was conditioned only on the passage of time. The allowance for doubtful accounts was insignificant as of both dates.
SUPPLEMENTAL CASH FLOW INFORMATION
The following table represents U.S. federal, state and international income taxes paid, refunds received and interest paid during the following periods:
| millions | Six months ended June 30, 2026 | Six months ended June 30, 2025 | ||||||
| Income tax payments | $ | 514 | $ | 877 | ||||
| Income tax refunds received | $ | (1) | $ | (3) | ||||
| Interest paid (a) | $ | 523 | $ | 681 |
(a) Net of capitalized interest of $103 million and $88 million for the six months ended June 30, 2026 and 2025, respectively.
INVENTORIES
Materials and supplies are valued at weighted-average cost and are reviewed periodically for obsolescence. Commodity inventory primarily represents oil, which is carried at the lower of weighted-average cost or net realizable value.
Inventories consisted of the following as of:
| millions | June 30, 2026 | December 31, 2025 | ||||||
| Materials and supplies | $ | 1,270 | $ | 1,222 | ||||
| Commodity inventory | 915 | 601 | ||||||
| Total | $ | 2,185 | $ | 1,823 |
ACCRUED LIABILITIES - CURRENT
Accrued liabilities - current consisted of the following as of:
| millions | June 30, 2026 | December 31, 2025 | ||||||
| Income tax payable | $ | 849 | $ | 159 | ||||
| Payroll and related expenses | 472 | 620 | ||||||
| Taxes other than on income | 467 | 498 | ||||||
| Accrued interest payable | 233 | 386 | ||||||
| Dividends payable | 408 | 383 | ||||||
| Asset retirement obligations | 400 | 381 | ||||||
| Operating lease liabilities | 378 | 350 | ||||||
| Other | 910 | 815 | ||||||
| Total | $ | 4,117 | $ | 3,592 |
OTHER LONG-TERM LIABILITIES
Other long-term liabilities consisted of the following as of:
| millions | June 30, 2026 | December 31, 2025 | ||||||
| Long-term tax liabilities | $ | 2,472 | $ | 2,393 | ||||
| Environmental remediation liabilities | 1,702 | 1,719 | ||||||
| Pension and postretirement obligations | 937 | 985 | ||||||
| Operating lease liabilities | 505 | 605 | ||||||
| Other | 1,602 | 1,609 | ||||||
| Total | $ | 7,218 | $ | 7,311 |
| NOTE 2 - REVENUE |
Revenue from customers is recognized when obligations under the terms of a contract with customers are satisfied; this generally occurs with the delivery of oil, NGL, gas or services, such as transportation.
The following table shows a reconciliation of revenue from customers to total net sales for the following periods:
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Revenue from customers | $ | 7,053 | $ | 5,163 | $ | 12,622 | $ | 10,976 | ||||||
| All other revenues (a) | 1,012 | 95 | 673 | (14) | ||||||||||
| Net sales | $ | 8,065 | $ | 5,258 | $ | 13,295 | $ | 10,962 |
(a) Includes other net revenues from the midstream and marketing segment.
DISAGGREGATION OF REVENUE FROM CONTRACTS WITH CUSTOMERS
The table below presents the Company's revenue from customers by segment, product and geographical area. The oil and gas segment typically sells its oil, NGL and gas at the lease or concession area. Midstream and marketing segment revenues are shown by the location of sale:
| millions | United States | International | Eliminations | Total | ||||||||||
| Three months ended June 30, 2026 | ||||||||||||||
| Oil and gas | ||||||||||||||
| Oil | $ | 5,417 | $ | 872 | $ | — | $ | 6,289 | ||||||
| NGL | 592 | 89 | — | 681 | ||||||||||
| Gas | (250) | 81 | — | (169) | ||||||||||
| Other | (26) | 2 | — | (24) | ||||||||||
| Segment total | $ | 5,733 | $ | 1,044 | $ | — | $ | 6,777 | ||||||
| Midstream and marketing | $ | 154 | $ | 265 | $ | — | $ | 419 | ||||||
| Eliminations | $ | — | $ | — | $ | (143) | $ | (143) | ||||||
| Consolidated | $ | 5,887 | $ | 1,309 | $ | (143) | $ | 7,053 | ||||||
| millions | United States | International | Eliminations | Total | ||||||||||
| Three months ended June 30, 2025 | ||||||||||||||
| Oil and gas | ||||||||||||||
| Oil | $ | 3,456 | $ | 690 | $ | — | $ | 4,146 | ||||||
| NGL | 457 | 86 | — | 543 | ||||||||||
| Gas | 205 | 88 | — | 293 | ||||||||||
| Other | 26 | 1 | — | 27 | ||||||||||
| Segment total | $ | 4,144 | $ | 865 | $ | — | $ | 5,009 | ||||||
| Midstream and marketing | $ | 134 | $ | 161 | $ | — | $ | 295 | ||||||
| Eliminations | $ | — | $ | — | $ | (141) | $ | (141) | ||||||
| Consolidated | $ | 4,278 | $ | 1,026 | $ | (141) | $ | 5,163 |
| millions | United States | International | Eliminations | Total | ||||||||||
| Six months ended June 30, 2026 | ||||||||||||||
| Oil and gas | ||||||||||||||
| Oil | $ | 9,290 | $ | 1,522 | $ | — | $ | 10,812 | ||||||
| NGL | 1,036 | 163 | — | 1,199 | ||||||||||
| Gas | (86) | 164 | — | 78 | ||||||||||
| Other | (2) | 4 | — | 2 | ||||||||||
| Segment total | $ | 10,238 | $ | 1,853 | $ | — | $ | 12,091 | ||||||
| Midstream and marketing | $ | 275 | $ | 541 | $ | — | $ | 816 | ||||||
| Eliminations | $ | — | $ | — | $ | (285) | $ | (285) | ||||||
| Consolidated | $ | 10,513 | $ | 2,394 | $ | (285) | $ | 12,622 |
| millions | United States | International | Eliminations | Total | ||||||||||
| Six months ended June 30, 2025 | ||||||||||||||
| Oil and gas | ||||||||||||||
| Oil | $ | 7,286 | $ | 1,365 | $ | — | $ | 8,651 | ||||||
| NGL | 1,035 | 182 | — | 1,217 | ||||||||||
| Gas | 586 | 172 | — | 758 | ||||||||||
| Other | 64 | 2 | — | 66 | ||||||||||
| Segment total | $ | 8,971 | $ | 1,721 | $ | — | $ | 10,692 | ||||||
| Midstream and marketing | $ | 278 | $ | 299 | $ | — | $ | 577 | ||||||
| Eliminations | $ | — | $ | — | $ | (293) | $ | (293) | ||||||
| Consolidated | $ | 9,249 | $ | 2,020 | $ | (293) | $ | 10,976 |
| NOTE 3 - LONG-TERM DEBT |
The Company's debt consisted of the following as of:
| millions | June 30, 2026 | December 31, 2025 | ||||||||||||||||||
| Two-year term loan due 2026 (5.475% as of December 31, 2025) | — | 1,280 | ||||||||||||||||||
| 3.200% senior notes due 2026 | — | 182 | ||||||||||||||||||
| 7.500% debentures due 2026 | — | 112 | ||||||||||||||||||
| 8.500% senior notes due 2027 | — | 489 | ||||||||||||||||||
| 3.000% senior notes due 2027 | — | 216 | ||||||||||||||||||
| 7.125% debentures due 2027 | — | 150 | ||||||||||||||||||
| 7.000% debentures due 2027 | 48 | 48 | ||||||||||||||||||
| 5.000% senior notes due 2027 | — | 600 | ||||||||||||||||||
| 6.625% debentures due 2028 | 14 | 14 | ||||||||||||||||||
| 7.150% debentures due 2028 | — | 232 | ||||||||||||||||||
| 7.200% senior debentures due 2028 | — | 82 | ||||||||||||||||||
| 6.375% senior notes due 2028 | — | 578 | ||||||||||||||||||
| 7.200% debentures due 2029 | 135 | 135 | ||||||||||||||||||
| 7.950% debentures due 2029 | 102 | 116 | ||||||||||||||||||
| 8.450% senior notes due 2029 | 116 | 116 | ||||||||||||||||||
| 3.500% senior notes due 2029 | — | 286 | ||||||||||||||||||
| 5.200% senior notes due 2029 | — | 1,200 | ||||||||||||||||||
| Variable rate bonds due 2030 | 68 | 68 | ||||||||||||||||||
| 8.875% senior notes due 2030 | 1,000 | 1,000 | ||||||||||||||||||
| 6.625% senior notes due 2030 | 856 | 1,449 | ||||||||||||||||||
| 6.125% senior notes due 2031 | 293 | 1,143 | ||||||||||||||||||
| 7.500% senior notes due 2031 | 900 | 900 | ||||||||||||||||||
| 7.875% senior notes due 2031 | 500 | 500 | ||||||||||||||||||
| 5.375% senior notes due 2032 | 748 | 1,000 | ||||||||||||||||||
| 5.550% senior notes due 2034 | 808 | 1,200 | ||||||||||||||||||
| 6.450% senior notes due 2036 | 1,727 | 1,727 | ||||||||||||||||||
| Zero Coupon senior notes due 2036 | 33 | 285 | ||||||||||||||||||
| 0.000% loan due 2039 (CAD denominated) | 15 | 17 | ||||||||||||||||||
| 4.300% senior notes due 2039 | 247 | 247 | ||||||||||||||||||
| 7.950% senior notes due 2039 | 325 | 325 | ||||||||||||||||||
| 6.200% senior notes due 2040 | 716 | 737 | ||||||||||||||||||
| 4.500% senior notes due 2044 | 184 | 191 | ||||||||||||||||||
| 4.625% senior notes due 2045 | 258 | 296 | ||||||||||||||||||
| 6.600% senior notes due 2046 | 986 | 1,117 | ||||||||||||||||||
| 4.400% senior notes due 2046 | 291 | 424 | ||||||||||||||||||
| 4.100% senior notes due 2047 | 224 | 258 | ||||||||||||||||||
| 4.200% senior notes due 2048 | 222 | 304 | ||||||||||||||||||
| 4.400% senior notes due 2049 | 245 | 280 | ||||||||||||||||||
| 6.050% senior notes due 2054 | 634 | 1,000 | ||||||||||||||||||
| 7.730% debentures due 2096 | 58 | 58 | ||||||||||||||||||
| 7.500% debentures due 2096 | 60 | 60 | ||||||||||||||||||
| 7.250% debentures due 2096 | 5 | 5 | ||||||||||||||||||
| Total borrowings at face value | $ | 11,818 | $ | 20,427 |
The following table summarizes the Company's outstanding debt, including finance lease liabilities, as of:
| millions | June 30, 2026 | December 31, 2025 | ||||||
| Total borrowings at face value | $ | 11,818 | $ | 20,427 | ||||
| Adjustments to book value: | ||||||||
| Unamortized premium, net | 1,030 | 1,054 | ||||||
| Debt issuance costs | (48) | (84) | ||||||
| Net book value of debt | $ | 12,800 | $ | 21,397 | ||||
| Long-term finance leases | 741 | 801 | ||||||
| Current finance leases | 202 | 198 | ||||||
| Total debt and finance leases | $ | 13,743 | $ | 22,396 | ||||
| Less: current finance leases | (202) | (198) | ||||||
| Less: current maturities of long-term debt | (1) | (1,575) | ||||||
| Long-term debt, net | $ | 13,540 | $ | 20,623 |
DEBT REDUCTION ACTIVITY
In the six months ended June 30, 2026, the Company utilized after-tax proceeds from the OxyChem Transaction and excess free cash flow to repay debt of $8.6 billion, which resulted in a loss on extinguishment of $190 million. The following table summarizes the Company's debt extinguishment in the six months ended June 30, 2026:
| millions | Borrowings at face value | ||||
| Total borrowings at face value as of December 31, 2025 | $ | 20,427 | |||
| Repayments | |||||
| Two-year term loan due 2026 | (1,280) | ||||
| 3.200% senior notes due 2026 | (182) | ||||
| 7.500% debentures due 2026 | (112) | ||||
| 3.000% senior notes due 2027 | (216) | ||||
| 5.000% senior notes due 2027 | (600) | ||||
| 7.125% debentures due 2027 | (150) | ||||
| 8.500% senior notes due 2027 | (489) | ||||
| 6.375% senior notes due 2028 | (578) | ||||
| 7.150% debentures due 2028 | (232) | ||||
| 7.200% senior debentures due 2028 | (82) | ||||
| 3.500% senior notes due 2029 | (286) | ||||
| 5.200% senior notes due 2029 | (1,200) | ||||
| 7.950% debentures due 2029 | (14) | ||||
| 6.625% senior notes due 2030 | (594) | ||||
| 6.125% senior notes due 2031 | (850) | ||||
| 5.375% senior notes due 2032 | (252) | ||||
| 5.550% senior notes due 2034 | (391) | ||||
| Zero Coupon senior notes due 2036 | (252) | ||||
| 0.000% loan due 2039 (CAD denominated) | (1) | ||||
| 4.300% senior notes due 2039 | (1) | ||||
| 6.200% senior notes due 2040 | (22) | ||||
| 4.500% senior notes due 2044 | (7) | ||||
| 4.625% senior notes due 2045 | (38) | ||||
| 6.600% senior notes due 2046 | (130) | ||||
| 4.400% senior notes due 2046 | (133) | ||||
| 4.100% senior notes due 2047 | (33) | ||||
| 4.200% senior notes due 2048 | (82) | ||||
| 4.400% senior notes due 2049 | (36) | ||||
| 6.050% senior notes due 2054 | (366) | ||||
| Total repayments | $ | (8,609) | |||
| Total borrowings at face value as of June 30, 2026 | $ | 11,818 |
FAIR VALUE OF DEBT
The estimated fair value of the Company's principal debt as of June 30, 2026 and December 31, 2025, the majority of which was classified as Level 1, was $12.2 billion and $20.8 billion, respectively.
| NOTE 4 - ACQUISITIONS, DIVESTITURES AND OTHER TRANSACTIONS |
ACQUISITIONS AND DIVESTITURES
During the second quarter of 2026, the Company divested non-core operated and non-operated leasehold interests as well as certain processing plants in the Permian Basin. The Company recorded a loss of $230 million primarily attributable to the processing plants for the first six months of 2026.
DISCONTINUED OPERATIONS
In October 2025, the Company announced a purchase and sale agreement with Berkshire Hathaway to sell all of the issued and outstanding equity interests in OxyChem in an all-cash transaction for an adjusted sales price of $9.5 billion, subject to additional post-closing adjustments. The sale was completed on January 2, 2026, resulting in a gain of approximately $3.1 billion, net of taxes. The OxyChem Transaction marks a strategic change in the Company's operations. For information related to the presentation of financials for discontinued operations, see Note 1 - General. Refer to Note 3 Long-Term Debt for the Company's use of the after-tax sale proceeds.
The following table summarizes the components of the sales price:
| in millions | Total | ||||
| Cash sales price | $ | 9,700 | |||
| Closing adjustments: | |||||
| Working capital adjustment | (158) | ||||
| Post-close adjustments | (70) | ||||
| Total cash sales price | $ | 9,472 |
The following table presents the amounts reported in discontinued operations, net of income taxes, for the following:
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Revenues and other income | ||||||||||||||
| Net sales | $ | — | $ | 1,156 | $ | 26 | $ | 2,255 | ||||||
| Interest, dividends and other income | 12 | (4) | 12 | 2 | ||||||||||
| Gains (losses) on sales of assets and other, net | (36) | 3 | 4,036 | 3 | ||||||||||
| Total revenues and other income | (24) | 1,155 | 4,074 | 2,260 | ||||||||||
| Costs and other deductions | ||||||||||||||
| Chemical cost of sales | — | 808 | 23 | 1,570 | ||||||||||
| General and administrative expense | 5 | 27 | 9 | 53 | ||||||||||
| Other operating and non-operating expense | 47 | 52 | 75 | 118 | ||||||||||
| Depreciation, depletion and amortization | — | 113 | — | 226 | ||||||||||
| Other expense, net | — | 5 | — | 13 | ||||||||||
| Total costs and other deductions | 52 | 1,005 | 107 | 1,980 | ||||||||||
| Income (loss) before income taxes and other items | (76) | 150 | 3,967 | 280 | ||||||||||
| Income from equity investments and other | — | 28 | 1 | 53 | ||||||||||
| Income (loss) before income taxes | (76) | 178 | 3,968 | 333 | ||||||||||
| Income tax benefit (expense) | 72 | (48) | (849) | (88) | ||||||||||
| Income (loss) from discontinued operations, net of tax | $ | (4) | $ | 130 | $ | 3,119 | $ | 245 |
The effective tax rate for discontinued operations was 21% and 26% for the six months ended June 30, 2026 and 2025, respectively.
| NOTE 5 - DERIVATIVES |
OBJECTIVE AND STRATEGY
The Company uses a variety of derivative financial instruments and physical contracts to manage its exposure to commodity price fluctuations and transportation commitments and to fix margins on the future sale of stored commodity volumes. Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty. The Company may occasionally use a variety of derivative financial instruments to manage its exposure to foreign currency fluctuations and interest rate risks. The Company also enters into derivative financial instruments for trading purposes.
The Company may elect normal purchases and normal sales exclusions when physically delivered commodities are purchased from a vendor or sold to a customer.
CRUDE COLLARS
In February 2026, the Company entered into crude two-way collar derivative instruments beginning in March for the remainder of 2026 to manage its near-term exposure to cash flow variability from crude oil price risk. A two-way collar is a combination of a sold call and a purchased put. The sold call establishes a ceiling price and the purchased put establishes a floor price that the Company will receive for the contracted commodity volume for a defined period of time. Gains and losses associated with changes in the fair value of the collars are recognized in net sales, and cash settlements are recognized in operating cash flows. The collars have a notional volume of 100 Mbbl per day, a floor WTI price of $55.00 per barrel and a weighted average ceiling WTI price of $75.89 per barrel.
MARKETING DERIVATIVES
The Company's marketing of derivative instruments includes short-duration physical and financial forward contracts. As of June 30, 2026, the weighted-average settlement price of these forward contracts was $82.03 per barrel and $2.29 per Mcf for crude oil and natural gas, respectively. The weighted-average settlement price was $59.59 per barrel and $2.53 per Mcf for crude oil and natural gas, respectively, as of December 31, 2025. Derivative instruments that are not designated as hedging instruments are required to be recorded on the balance sheet at fair value. Changes in fair value will impact the Company's earnings through mark-to-market adjustments until the physical commodity is delivered or the financial instrument is settled. Net gains and losses associated with marketing derivative instruments are recognized currently in net sales. Cash settlements related to marketing derivatives are presented in operating cash flows.
The following table summarizes net volumes associated with the outstanding marketing commodity derivatives as of:
| long (short) | June 30, 2026 | December 31, 2025 | ||||||
| Oil commodity contracts | ||||||||
| Volume (MMbbl) | (52) | (59) | ||||||
| Natural gas commodity contracts | ||||||||
| Volume (Bcf) | (307) | (189) |
FAIR VALUE OF DERIVATIVES
The following tables present the fair values of the Company's outstanding derivatives. Fair values are presented at gross amounts below, including when the derivatives are subject to netting arrangements, and are presented on a net basis in the Consolidated Condensed Balance Sheets:
| millions | Fair Value Measurements Using | Netting (a) | Total Fair Value | ||||||||||||||
| Balance Sheet Classifications | Level 1 | Level 2 | Level 3 | ||||||||||||||
| June 30, 2026 | |||||||||||||||||
| Marketing Derivatives | |||||||||||||||||
| Other current assets | $ | 2,261 | $ | 416 | $ | — | $ | (2,385) | $ | 292 | |||||||
| Other long-term assets | 2 | — | — | (2) | — | ||||||||||||
| Accrued liabilities | (2,140) | (279) | — | 2,385 | (34) | ||||||||||||
| Deferred credits and other liabilities - other | (2) | — | — | 2 | — | ||||||||||||
| Crude Collars | |||||||||||||||||
| Accrued liabilities | (31) | — | — | — | (31) | ||||||||||||
| December 31, 2025 | |||||||||||||||||
| Marketing Derivatives | |||||||||||||||||
| Other current assets | $ | 345 | $ | 51 | $ | — | $ | (328) | $ | 68 | |||||||
| Accrued liabilities | (336) | (24) | — | 328 | (32) | ||||||||||||
(a)These amounts do not include collateral. The Company netted $71 million of collateral received from brokers against derivative assets as of June 30, 2026. As of December 31, 2025, the Company netted $29 million of collateral received from brokers against derivative assets and $23 million of collateral deposited with brokers against derivative liabilities.
GAINS AND LOSSES ON DERIVATIVES
The following table presents gains and losses related to the Company's derivative instruments and the location on the Consolidated Condensed Statements of Operations:
| millions | Three months ended | Six months ended | ||||||||||||
| Income Statement Classification | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Marketing derivatives (included in net sales) | $ | 908 | $ | 97 | $ | 910 | $ | (10) | ||||||
| Crude collars (included in net sales) | $ | 105 | $ | — | $ | (234) | $ | — | ||||||
CREDIT RISK
The majority of the Company's credit risk is related to the physical delivery of energy commodities to its counterparties and their potential inability to meet their settlement commitments. The Company manages credit risk by selecting counterparties that it believes to be financially strong, by entering into netting arrangements with counterparties and by requiring collateral or other credit risk mitigants, as appropriate. The Company actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. The Company also enters into futures contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk, if any.
| NOTE 6 - INCOME TAXES |
The following table summarizes components of income tax expense:
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Income before income taxes | $ | 3,915 | $ | 560 | $ | 4,305 | $ | 1,737 | ||||||
| Current | ||||||||||||||
| Federal | 19 | (57) | 29 | (387) | ||||||||||
| State and Local | (5) | (4) | (3) | (17) | ||||||||||
| Foreign | (222) | (173) | (338) | (302) | ||||||||||
| Total current tax expense | $ | (208) | $ | (234) | $ | (312) | $ | (706) | ||||||
| Deferred | ||||||||||||||
| Federal | (650) | 39 | (678) | 178 | ||||||||||
| State and Local | (27) | (1) | (30) | 3 | ||||||||||
| Foreign | (30) | (26) | (49) | (44) | ||||||||||
| Total deferred tax benefit (expense) | $ | (707) | $ | 12 | $ | (757) | $ | 137 | ||||||
| Total income tax expense | ||||||||||||||
| Federal | (631) | (18) | (649) | (209) | ||||||||||
| State and Local | (32) | (5) | (33) | (14) | ||||||||||
| Foreign | (252) | (199) | (387) | (346) | ||||||||||
| Total income tax expense | $ | (915) | $ | (222) | $ | (1,069) | $ | (569) | ||||||
| Income from continuing operations | $ | 3,000 | $ | 338 | $ | 3,236 | $ | 1,168 | ||||||
| Worldwide effective tax rate | 23 | % | 40 | % | 25 | % | 33 | % |
The worldwide effective tax rates for the periods presented in the table above were primarily driven by the Company's jurisdictional mix of income from continuing operations. U.S. income is taxed at a U.S. federal statutory rate of 21%, while international income is subject to tax at statutory rates as high as 55%.
| NOTE 7 - ENVIRONMENTAL LIABILITIES AND EXPENDITURES |
The Company and its subsidiaries and their respective operations are subject to stringent federal, regional, state, provincial, tribal, local and international laws and regulations related to improving or maintaining environmental quality. The laws that require or address environmental remediation, including CERCLA and similar federal, regional, state, provincial, tribal, local and international laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership or control of sites. The Company or certain of its subsidiaries participate in or actively monitor a range of remedial activities and government or private proceedings under these laws with respect to alleged past practices at Third-Party, Currently Operated, and Closed or Non-operated Sites, in addition to NPL Sites. Remedial activities may include one or more of the following: investigation involving sampling, modeling, risk assessment or monitoring; clean-up measures including removal, treatment or disposal; or operation and maintenance of remedial systems. The environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, natural resource damages, punitive damages, civil penalties, injunctive relief and government oversight costs.
As discussed in Note 1 - General, certain Occidental subsidiaries, including Environmental Resource Holdings, LLC (ERH), remain responsible for environmental remediation at legacy sites and the indemnification of legacy environmental liabilities and pre-closing liabilities of OxyChem, which were not classified as held for sale. Expenses related to the oil and gas and midstream businesses are reported as continuing operations for all periods presented. Expenses related to OxyChem and the retained liabilities and indemnification obligations associated with the chemical business are reported as discontinued operations for all periods presented, reflecting the OxyChem Transaction.
ENVIRONMENTAL REMEDIATION
As of June 30, 2026, the Company participated in or monitored remedial activities or proceedings at 149 sites. The following table presents the current and non-current environmental remediation liabilities of the Company:
| millions | as of June 30, 2026 | as of December 31, 2025 | ||||||||||||||||||
| Continuing Operations | Discontinued Operations | Total | Continuing Operations | Discontinued Operations | Total | |||||||||||||||
| Current Portion: | ||||||||||||||||||||
| Accrued liabilities | $ | 55 | $ | 96 | $ | 151 | $ | 55 | $ | 96 | $ | 151 | ||||||||
| Non-Current Portion: | ||||||||||||||||||||
| Other deferred credits and liabilities | 135 | 1,567 | 1,702 | 141 | 1,578 | 1,719 | ||||||||||||||
| Total current and non-current | $ | 190 | $ | 1,663 | $ | 1,853 | $ | 196 | $ | 1,674 | $ | 1,870 | ||||||||
The estimates of environmental remediation liabilities in the table above vary over time depending on factors such as acquisitions or divestitures, identification of additional sites, remedy selection and implementation and changes in applicable laws or regulations, among other factors. Environmental remediation expenses primarily relate to existing conditions from alleged past practices.
Environmental remediation sites are grouped into NPL Sites and the following three categories of non-NPL Sites — Third-Party Sites, Currently Operated Sites and Closed or Non-operated Sites.
| June 30, 2026 | ||||||||
| millions, except number of sites | Number of Sites | Remediation Balance | ||||||
| NPL Sites | 29 | $ | 1,367 | |||||
| Third-Party Sites | 68 | 247 | ||||||
| Currently Operated Sites | 3 | 25 | ||||||
| Closed or Non-operated Sites | 49 | 214 | ||||||
| Total | 149 | $ | 1,853 |
As of June 30, 2026, environmental remediation liabilities of Occidental subsidiaries exceeded $10 million each at 15 of the 149 sites described above, and 85 of the sites had liabilities less than $1 million each. Based on current estimates, the Company expects its subsidiaries to expend funds corresponding to approximately 30% of the remediation balance over the next three to four years with the remainder over the subsequent 10 or more years.
The Company believes the range of reasonably possible additional losses of its subsidiaries beyond those amounts currently recorded for environmental remediation for the 149 environmental sites in the table above could be up to $1.9 billion. The status of the Company's involvement with the sites and related significant assumptions have not changed materially since December 31, 2025.
DIAMOND ALKALI SUPERFUND SITE
The EPA has organized the DASS into four OUs for evaluating, selecting and implementing remediation under CERCLA. Current activities in each OU are summarized below, many of which are performed by Glenn Springs Holdings, Inc.
OU1 – 80 and 120 Lister Avenue in Newark, New Jersey: Glenn Springs Holdings, Inc. currently performs maintenance and monitoring for the interim remedy of OU1 pursuant to a 1990 Consent Decree for which such subsidiary inherited legal responsibility. In January 2025, the EPA issued a ROD for the final remedy of OU1 that provides for optimized containment for which it estimated a cost of $16 million.
OU2 – The Lower 8.3 Miles of the Lower Passaic River: In March 2016, the EPA issued a ROD specifying remedial actions required for OU2. During the third quarter of 2016, the EPA and an Occidental subsidiary entered into an AOC to complete the design of the remedy selected in the ROD. In May 2024, the EPA approved the remedial design for OU2. In June 2024, the EPA notified the subsidiary that the work required by the AOC has been fully performed in accordance with its terms. The EPA has estimated the cost to remediate OU2 to be approximately $1.4 billion.
OU3 – Newark Bay Study Area, including Newark Bay and portions of the Hackensack River, Arthur Kill, and Kill van Kull: A remedial investigation and feasibility study of OU3 was launched pursuant to a 2004 AOC which was amended in 2010. An Occidental subsidiary is currently performing feasibility study activities in OU3.
OU4 – The 17-mile Lower Passaic River Study Area, comprising OU2 and the Upper 9 Miles of the Lower Passaic River: In September 2021, the EPA issued a ROD selecting an interim remedy for the portion of OU4 that excludes OU2 and is located upstream from the Lister Avenue Plant site for which an Occidental subsidiary inherited legal responsibility. In March 2023, the EPA issued a Unilateral Administrative Order in which it directed and ordered such subsidiary to design the EPA's selected interim remedy for OU4. The EPA has estimated the cost to remediate OU4 to be approximately $440 million.
Natural Resource Trustees – In addition to the activities described above, federal and state natural resource trustees are assessing natural resources in the Lower Passaic River and Greater Newark Bay to evaluate potential claims for natural resource damages.
Legal matters related to the DASS (Alden Leeds)
In December 2022, the EPA and the DOJ filed a proposed Consent Decree in the Alden Leeds litigation, seeking court approval to settle with 85 parties for a total of $150 million for cleanup costs associated with OU2 and OU4. In January 2024, the DOJ filed a proposed Amended Consent Decree that excluded three companies from the original settlement, among other changes, and subsequently filed a motion to approve the Amended Consent Decree. In December 2024, the U.S. District Court for the District of New Jersey (District Court) approved the Amended Consent Decree. In its order approving the Amended Consent Decree, the District Court accepted the EPA's revised determination that the Company was responsible for approximately 85% of the cleanup costs for OU2 and OU4. ERH appealed the District Court's ruling on the grounds that the decision was flawed for several reasons, including the failure to consider the impact of recent Supreme Court decisions that restrict EPA authority and limit judicial deference to EPA actions. The Notice of Appeal was filed in February 2025, and all briefs have been filed as of January 2026.
As a result of the District Court's approval of the Amended Consent Decree, the non-current environmental remediation liability related to OU2 and OU4 was increased by $925 million in the fourth quarter of 2024. This charge was included in asset impairments and other charges in the Company's Consolidated Statements of Operations and represented the additional share of the total estimated remediation costs which may be incurred because of the assignment by the District Court of 85% of the responsibility for OU2 and OU4. These costs have not been discounted as the timing and amount of the payments are not fixed or reliably determinable. It is expected that the cash outlay for remediation costs will be expended over ten to twenty years, or more.
The Alden Leeds settlement does not address the liability of entities that were excluded from the settlement, including for OU2, OU3, OU4 or natural resource damages, or the liability of any settling party with respect to OU3 or natural resource damages.
While the remedies for OU2 and OU4 are expected to take ten to twenty years to complete, the EPA may seek to require the Company to perform a substantial majority or all of the remediation work and provide additional financial assurance. It is uncertain when or to what extent the EPA may take action to compel further remediation in OU2 or OU4, or the amount of financial assurance that could be required.
In June 2018, the Company filed a complaint under CERCLA in the District Court against numerous potentially responsible parties seeking contribution and cost recovery of amounts incurred or to be incurred to comply with the AOC and the OU2 ROD, or to perform other remediation activities related to the DASS (2018 Contribution Action). Because costs are being incurred to implement the OU4 Unilateral Administrative Order, a cost recovery action under CERCLA was brought
in March 2023 in the District Court against multiple parties (2023 Cost Recovery Action). Both the 2018 Contribution Action and the 2023 Cost Recovery Action were stayed pending the outcome of the Alden Leeds litigation. The Company does not know when the Court will lift the stay in those matters. If not reversed on appeal, the approved Amended Consent Decree could bar the Company from pursuing contribution against the settling parties for remediation costs incurred or that may be incurred in the future to design and implement the remedies in OU2 and OU4, including claims asserted in the 2018 Contribution Action.
Other information
For the DASS, a reserve has been accrued relating to the estimated allocable share of the costs to perform the maintenance and monitoring required in the OU1 Consent Decree, as well as the remedial investigation and feasibility study required in OU3 (Newark Bay). Subject to and without waiver of any rights, including appeal, a reserve has also been accrued for design and implementation of remedies selected in the OU2 ROD and AOC, and the OU4 ROD and OU4 Unilateral Administrative Order, based on the December 2024 Order of the District Court approving the Amended Consent Decree described above, which Order is currently being appealed.
The accrued environmental remediation reserve does not account for the possibility of additional remediation costs or natural resource damages for the DASS that are not considered reasonably estimable. The ultimate liability at the DASS may be greater or less than both the reserved amount and any reasonably possible additional losses, and will depend on final design plans, future actions by the EPA and natural resource trustees, as well as the resolution of the allocable share with other potentially responsible parties, among other factors.
The estimated costs currently recorded for remediation at the DASS and the range of reasonably possible additional losses beyond the amounts currently recognized are evaluated periodically. Due to the complexity and scope of the remediation efforts, the estimated costs may fluctuate over time as new information becomes available.
| NOTE 8 - LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES |
LEGAL MATTERS
The Company is involved, in the normal course of business, in lawsuits, claims and other legal proceedings that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. The Company also is involved in proceedings under CERCLA and similar federal, regional, state, provincial, tribal, local and international environmental laws. These environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, natural resource damages, punitive damages, civil penalties, injunctive relief and government oversight costs. Usually the Company is among many companies in these environmental proceedings and has to date been successful in sharing remediation costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or divested assets with respect to which a third party or the Company retains liability or indemnifies the other party for conditions that existed prior to the transaction.
In accordance with applicable accounting guidance, the Company accrues contingency reserves for outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Contingency reserves for matters, other than for tax matters discussed below and environmental matters discussed in Note 7 – Environmental Liabilities and Expenditures, that satisfy these criteria as of June 30, 2026 were not material to the Company's Consolidated Condensed Balance Sheets.
If unfavorable outcomes of these matters were to occur, future results of operations or cash flows for any particular quarterly or annual period could be materially adversely affected. The Company's estimates are based on information known about the legal matters and its experience in contesting, litigating and settling similar matters. The Company will reassess the probability and estimability of contingent losses as new information becomes available.
TAX MATTERS AND DISPUTES
During the course of its operations, the Company is subject to audit by tax authorities for varying periods in various federal, state, local and international tax jurisdictions. Tax years through 2021 for U.S. federal income tax purposes have been audited by the IRS pursuant to its Compliance Assurance Program and subsequent taxable years are currently under review. Tax years through 2018 have been audited for state income tax purposes. There are no outstanding significant audit matters in international jurisdictions. During the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law.
The IRS is currently reviewing the legal entity reorganization transaction as part of the Company's 2022 federal tax audit. Following the acquisition of Anadarko and related divestitures, the Company reorganized its legal entities to better align with the nature of its business activities. This reorganization resulted in the Company making an adjustment to the tax basis in a portion of its operating assets, reducing deferred tax liabilities and recording a $2.7 billion tax benefit in 2022.
For Anadarko, its taxable years through 2014 and tax year 2016 for U.S. federal tax purposes have been audited and closed by the IRS. Tax years 2015 and 2017 through 2019 have been audited by the IRS but remain open pending the outcome of the Tronox U.S. Tax Court litigation discussed below. Tax years through 2018 have been audited for state income tax purposes. There are no outstanding significant audit matters in international jurisdictions. As stated above, during the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law.
Other than the dispute discussed below, the Company believes that the resolution of these outstanding tax disputes would not have a material adverse effect on its consolidated financial position or results of operations.
Anadarko received an $881 million tentative refund in 2016 related to its $5.2 billion Tronox Adversary Proceeding settlement payment in 2015. In September 2018, Anadarko received a statutory notice of deficiency from the IRS disallowing the net operating loss carryback and rejecting Anadarko's refund claim. Anadarko disagreed and, in November 2018, filed a petition with the U.S. Tax Court to dispute the disallowance. Trial was held in May 2023. The parties filed post-trial briefs throughout 2023 and 2024. Closing arguments were held in May 2024. The Tax Court may issue an opinion at any time. If the Tax Court opines that all or a portion of the original $5.2 billion deduction is not deductible, a computation phase will commence where the parties will compute the tax amount to be included in the Tax Court's decision. Once the parties submit their computation, the Tax Court will formally enter the decision reflecting the computed tax amount. To pursue an appeal of the Tax Court's decision, any tax due as a result of the Tax Court's decision must be fully bonded or paid within 90 days of the decision's entry. If Anadarko does not pursue an appeal, the IRS will assess any resulting tax deficiency, including interest, and issue a notice demanding payment thereof.
In accordance with ASC 740's guidance on the accounting for uncertain tax positions, the Company has recorded no tax benefit on the tentative cash tax refund of $881 million. Additionally, the Company has recorded no tax benefit on approximately $500 million of additional cash tax benefits realized from the utilization of tax attributes generated as a result of the deduction of the $5.2 billion Tronox Adversary Proceeding settlement payment in 2015. If the payment is ultimately determined not to be deductible, the Company would be required to repay the tentative refund received, plus other cash benefits received related to the $5.2 billion deduction, plus interest, which as of June 30, 2026 totaled approximately $2.4 billion. As a result, should the Company not ultimately prevail on the issue, there would be no additional tax expense recorded relative to this position for financial statement purposes other than future interest. However, in that event, as of June 30, 2026, the Company would be required to repay approximately $1.4 billion in federal and state taxes and accrued interest of $1.0 billion. A liability for the taxes and interest is included in other liabilities.
INDEMNITIES TO THIRD PARTIES
The Company has indemnified various parties against specified liabilities those parties might incur in the future in connection with purchases and other transactions that they have entered into with the Company. These indemnities usually are contingent upon the other party incurring liabilities that reach specified thresholds. The Company reserves for indemnity claims when a payment for such claims is probable and estimable. As discussed in Note 1 - General, Berkshire Hathaway has post-closing indemnification rights in connection with the OxyChem Transaction.
| NOTE 9 - EARNINGS PER SHARE AND EQUITY |
The following table presents the calculation of basic and diluted EPS attributable to common stockholders:
| Three months ended | Six months ended | |||||||||||||
| millions except per-share amounts | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Income from continuing operations | $ | 3,000 | $ | 338 | $ | 3,236 | $ | 1,168 | ||||||
| Discontinued operations, net of taxes | (4) | 130 | 3,119 | 245 | ||||||||||
| Net income | $ | 2,996 | $ | 468 | $ | 6,355 | $ | 1,413 | ||||||
| Less: Income attributable to noncontrolling interest | (19) | (10) | (33) | (19) | ||||||||||
| Less: Preferred stock dividends | (170) | (170) | (340) | (340) | ||||||||||
| Net income attributable to common stock | $ | 2,807 | $ | 288 | $ | 5,982 | $ | 1,054 | ||||||
| Less: Incremental fair value for warrants inducement | — | (25) | — | (25) | ||||||||||
| Less: Net income allocated to participating securities | (20) | (2) | (37) | (7) | ||||||||||
| Net income, net of participating securities | $ | 2,787 | $ | 261 | $ | 5,945 | $ | 1,022 | ||||||
| Weighted-average number of basic shares | 997.1 | 985.1 | 993.7 | 963.5 | ||||||||||
| Basic income per common share | $ | 2.80 | $ | 0.27 | $ | 5.98 | $ | 1.06 | ||||||
| Net income attributable to common stock | $ | 2,807 | $ | 288 | $ | 5,982 | $ | 1,054 | ||||||
| Less: Incremental fair value for warrants inducement | — | (25) | — | (25) | ||||||||||
| Less: Net income allocated to participating securities | (19) | (2) | (37) | (7) | ||||||||||
| Net income, net of participating securities | $ | 2,788 | $ | 261 | $ | 5,945 | $ | 1,022 | ||||||
| Weighted-average number of basic shares | 997.1 | 985.1 | 993.7 | 963.5 | ||||||||||
| Dilutive securities | 15.1 | 25.3 | 16.1 | 33.5 | ||||||||||
| Total diluted weighted-average common shares | 1,012.2 | 1,010.4 | 1,009.8 | 997.0 | ||||||||||
| Diluted income per common share | $ | 2.75 | $ | 0.26 | $ | 5.89 | $ | 1.03 | ||||||
| Anti-dilutive securities excluded from diluted shares (millions) | 83.9 | 84.2 | 83.9 | 83.9 |
The following table presents Occidental's common share activity, including exercises of warrants, and other transactions in Occidental's common stock in 2026:
| Period | Exercise of Warrants (a) | Other (b) | Treasury Stock Purchases (c) | Common Stock Outstanding | |||||||||||||
| December 31, 2025 | 986,026,416 | ||||||||||||||||
| First Quarter 2026 | 3,609,243 | 2,939,668 | (1,382,767) | 991,192,560 | |||||||||||||
| Second Quarter 2026 | 8,929,988 | 222,559 | (636,556) | 999,708,551 | |||||||||||||
| Total | 12,539,231 | 3,162,227 | (2,019,323) | 999,708,551 |
(a) $276 million of cash was received in the first six months of 2026 from the exercise of Common Stock Warrants.
(b) Includes issuances under the 2015 long-term incentive plan and the OPC savings plan.
(c) Includes purchases from the trustee of Occidental's defined contribution savings plan that are not part of publicly announced plans or programs.
As of June 30, 2026, Occidental had 17.9 million Common Stock Warrants with a strike of $22.00 per share and 83.9 million Berkshire Warrants held by Berkshire Hathaway with a strike of $59.59 per share.
On March 3, 2025, Occidental announced an offer to holders of its Common Stock Warrants to exercise their warrants, each exercisable at $22.00, at a temporarily reduced price of $21.30 per share with an expiration date of March 31, 2025. In April 2025, Occidental issued 41.9 million shares of stock in return for proceeds of approximately $890 million. The incremental fair value associated with the Common Stock Warrants related to the change in exercise price was recognized as an equity issuance cost. The proceeds from the warrant exercise were used to repay near-term debt maturities.
| NOTE 10 - SEGMENTS |
The Company conducts its operations through two segments: oil and gas and midstream and marketing. Income taxes, interest income, interest expense, environmental remediation expenses and unallocated corporate expenses are included under corporate and eliminations. Intersegment sales eliminate upon consolidation and are made at prices that approximate market. Identifiable assets are those assets used in the operations of the segments. Corporate assets consist of cash and restricted cash, certain corporate receivables and PP&E.
As a result of the OxyChem Transaction, the chemical segment results are presented separately as discontinued operations and corporate costs directly attributable to the chemical segment are included under discontinued operations. See Note 1 - General for related disclosure.
Occidental's President and CEO is ultimately responsible for allocating resources and assessing the performance of each operating segment and is the Chief Operating Decision Maker. The CEO may be assisted in this function by other members of Occidental's executive management including, but not limited to, the Chief Financial Officer. While other executives are responsible for the performance of their individual areas, the CEO is solely responsible for allocating resources across the Company as a whole.
For both reporting segments, segment income (loss) from continuing operations before income taxes is used to measure performance, as well as allocate resources (including financial or capital resources) for each segment, predominantly in the annual budget and forecasting process.
The following table reconciles segment income from continuing operations before taxes to net income attributable to common shares:
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Segment income (losses) from continuing operations before taxes | ||||||||||||||
| Oil and gas segment | $ | 2,849 | $ | 934 | $ | 3,866 | $ | 2,631 | ||||||
| Midstream and marketing segment | 1,338 | 39 | 1,251 | (33) | ||||||||||
| Corporate and eliminations | (164) | (142) | (272) | (280) | ||||||||||
| Interest and debt expense, net | (108) | (271) | (540) | (581) | ||||||||||
| Income from continuing operations before income taxes | $ | 3,915 | $ | 560 | $ | 4,305 | $ | 1,737 | ||||||
| Income tax expense | (915) | (222) | (1,069) | (569) | ||||||||||
| Income from continuing operations | $ | 3,000 | $ | 338 | $ | 3,236 | $ | 1,168 | ||||||
| Discontinued operations, net of tax | (4) | 130 | 3,119 | 245 | ||||||||||
| Net income | $ | 2,996 | $ | 468 | $ | 6,355 | $ | 1,413 | ||||||
| Less: Net income attributable to noncontrolling interest | (19) | (10) | (33) | (19) | ||||||||||
| Less: Preferred stock dividends | (170) | (170) | (340) | (340) | ||||||||||
| Net income attributable to common stockholders | $ | 2,807 | $ | 288 | $ | 5,982 | $ | 1,054 |
The following tables include a summary of significant revenue and expense line items for each segment. Items within "Significant segment expenses" align with the significant segment-level information that is regularly provided to the Chief Operating Decision Maker.
OIL AND GAS SEGMENT
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Revenues and other income | ||||||||||||||
| Net sales (a) | $ | 6,882 | $ | 5,009 | $ | 11,857 | $ | 10,692 | ||||||
| Losses on sale of assets and other, net | (13) | (2) | (42) | (8) | ||||||||||
| Total | $ | 6,869 | $ | 5,007 | $ | 11,815 | $ | 10,684 | ||||||
| Significant segment expenses | ||||||||||||||
| Oil and gas lease operating expense | 1,117 | 1,135 | 2,235 | 2,352 | ||||||||||
| Transportation and gathering expense | 395 | 403 | 786 | 810 | ||||||||||
| Other operating and non-operating expense | 272 | 357 | 545 | 601 | ||||||||||
| Taxes other than on income | 338 | 262 | 590 | 522 | ||||||||||
| Depreciation, depletion and amortization | 1,745 | 1,718 | 3,435 | 3,420 | ||||||||||
| Other segment expenses (b) | 135 | 187 | 338 | 337 | ||||||||||
| Total | $ | 4,002 | $ | 4,062 | $ | 7,929 | $ | 8,042 | ||||||
| Segment income before other items | $ | 2,867 | $ | 945 | $ | 3,886 | $ | 2,642 | ||||||
| Losses from equity investments and other | (18) | (11) | (20) | (11) | ||||||||||
| Segment income from continuing operations before taxes | $ | 2,849 | $ | 934 | $ | 3,866 | $ | 2,631 | ||||||
(a) Includes revenue from customers and all other revenues.
(b) Includes general and administrative expense and exploration expense.
MIDSTREAM AND MARKETING SEGMENT
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Revenues and other income | ||||||||||||||
| Net sales (a) | $ | 1,326 | $ | 390 | $ | 1,723 | $ | 563 | ||||||
| Gains on sale of assets and other income, net | 225 | 39 | 76 | 66 | ||||||||||
| Total | $ | 1,551 | $ | 429 | $ | 1,799 | $ | 629 | ||||||
| Significant segment expenses | ||||||||||||||
| Transportation and gathering expense | 219 | 197 | 403 | 400 | ||||||||||
| Other operating and non-operating expense | 54 | 95 | 133 | 176 | ||||||||||
| Depreciation, depletion and amortization | 68 | 74 | 139 | 147 | ||||||||||
| Asset impairments and other charges | — | — | 105 | — | ||||||||||
| Other segment expenses (b) | 24 | 31 | 58 | 60 | ||||||||||
| Total | $ | 365 | $ | 397 | $ | 838 | $ | 783 | ||||||
| Segment income (losses) before other items | $ | 1,186 | $ | 32 | $ | 961 | $ | (154) | ||||||
| Income from equity investments and other | 152 | 7 | 290 | 121 | ||||||||||
| Segment income (losses) from continuing operations before taxes | $ | 1,338 | $ | 39 | $ | 1,251 | $ | (33) | ||||||
(a) Includes revenue from customers and all other revenues.
(b) Includes taxes other than on income and general and administrative expense.
SEGMENT PROPERTY PLANT AND EQUIPMENT AND INVESTMENTS
The following table includes segment-level additions to property, plant and equipment:
| Three months ended | Six months ended | |||||||||||||
| millions | June 30, 2026 | June 30, 2025 | June 30, 2026 | June 30, 2025 | ||||||||||
| Oil and gas | $ | 1,481 | $ | 1,541 | $ | 2,883 | $ | 3,109 | ||||||
| Midstream and marketing | 142 | 188 | 334 | 336 | ||||||||||
| Corporate and eliminations | 19 | 22 | 29 | 30 | ||||||||||
| Total | $ | 1,642 | $ | 1,751 | $ | 3,246 | $ | 3,475 | ||||||
The following table includes segment-level balance sheet information:
| millions | Oil and gas | Midstream and marketing | Corporate and eliminations | Assets held for sale | Total | ||||||||||||
| As of June 30, 2026 | |||||||||||||||||
| Property Plant and Equipment, Gross | $ | 124,245 | $ | 8,930 | $ | 1,234 | $ | — | $ | 134,409 | |||||||
| Accumulated DD&A | (68,619) | (2,592) | (598) | — | (71,809) | ||||||||||||
| Property, Plant and Equipment, Net | $ | 55,626 | $ | 6,338 | $ | 636 | $ | — | $ | 62,600 | |||||||
| Investments in unconsolidated entities | $ | 148 | $ | 2,421 | $ | — | $ | — | $ | 2,569 | |||||||
| Total Assets | $ | 59,531 | $ | 14,883 | $ | 5,944 | $ | — | $ | 80,358 | |||||||
| As of December 31, 2025 | |||||||||||||||||
| Property Plant and Equipment, Gross | $ | 126,896 | $ | 9,638 | $ | 1,219 | $ | — | $ | 137,753 | |||||||
| Accumulated DD&A | (70,292) | (3,273) | (545) | — | (74,110) | ||||||||||||
| Property, Plant and Equipment, Net | $ | 56,604 | $ | 6,365 | $ | 674 | $ | — | $ | 63,643 | |||||||
| Investments in unconsolidated entities | $ | 129 | $ | 2,346 | $ | — | $ | — | $ | 2,475 | |||||||
| Total Assets | $ | 60,393 | $ | 13,901 | $ | 3,372 | $ | 6,520 | $ | 84,186 |
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