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Summary of Significant Accounting Policies | 12 Months Ended
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Dec. 31, 2024
Accounting Policies [Abstract] |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies Nature of Operations. EQT Corporation is an integrated natural gas company with production, gathering and transmission operations focused in the Appalachian Basin. In this Annual Report on Form 10-K, references to "EQT" refer to EQT Corporation and references to the "Company" refer collectively to EQT Corporation and its consolidated subsidiaries, collectively, in each case unless otherwise noted or indicated. Principles of Consolidation and Noncontrolling Interests. The Consolidated Financial Statements include the accounts of EQT and all subsidiaries, ventures and partnerships in which EQT directly or indirectly holds a controlling interest and variable interest entities for which EQT is the primary beneficiary. Intercompany accounts and transactions have been eliminated in consolidation. The Company records noncontrolling interest in its Consolidated Financial Statements for any non-wholly-owned consolidated subsidiary. Upon the completion of the Midstream Joint Venture Transaction (defined in Note 8) and as of December 31, 2024, the Company consolidates its controlling interest in the Midstream Joint Venture (defined in Note 8) under the voting interest entity model. See Note 8 for discussion of the formation of the Midstream Joint Venture, the completion of the Midstream Joint Venture Transaction and the method of allocation used in accounting for the portion of Midstream Joint Venture that is not owned by the Company. In addition, upon the completion of the Equitrans Midstream Merger (defined in Note 6) and as of December 31, 2024, the Company consolidates its 60% interest in Eureka Midstream Holdings, LLC (Eureka Midstream Holdings), a joint venture that owns a gathering header pipeline system that is operated by a subsidiary of EQT, under the voting interest entity model. See Note 10 for discussion of the revolving credit facility of Eureka Midstream, LLC (Eureka), a wholly-owned subsidiary of Eureka Midstream Holdings. In 2020, the Company entered into a partnership with a third-party investor (the Investor) to form a joint venture, The Mineral Company LLC, for the purpose of purchasing certain mineral rights in the Appalachian Basin. During 2023, The Mineral Company LLC's assets were distributed pro rata to the Company and the Investor, and The Mineral Company LLC was dissolved. Prior to The Mineral Company LLC's dissolution, the Company consolidated The Mineral Company LLC as management had determined that The Mineral Company LLC was a variable interest entity, and the Company was the primary beneficiary of The Mineral Company LLC. Prior to the NEPA Gathering System Acquisition (defined in Note 6) and the First NEPA Non-Operated Asset Divestiture (defined in Note 7), the Company recorded in the Consolidated Financial Statements its pro rata share of revenues, expenses, assets and liabilities of the NEPA Gathering System (defined in Note 6). Following the completion of the First NEPA Non-Operated Asset Divestiture, the Company owns 100% of the NEPA Gathering System. Segments. The Company has three reportable segments reflective of its three lines of business consisting of Production, Gathering and Transmission. See Note 2. Reclassification. Certain previously reported amounts have been reclassified to conform to the current year presentation. In addition, as discussed further in Note 2, certain prior period amounts have been recast to reflect the Company's change in reportable segments from one reportable segment to three reportable segments consisting of Production, Gathering and Transmission. Use of Estimates. The preparation of financial statements in conformity with United States generally accepted accounting principles (GAAP) requires management to make estimates and assumptions that affect the amounts reported herein. Actual results could differ from those estimates. Cash and Cash Equivalents. The Company considers all highly-liquid investments with an original maturity of three months or less when purchased to be cash equivalents and accounts for such investments at cost. Interest earned on cash equivalents is included as a reduction of interest expense, net. Accounts Receivable, Net of Allowance for Credit Losses. The Company's accounts receivable relates primarily to the sales of natural gas, natural gas liquids (NGLs) and oil and amounts due from joint interest partners. See Note 3 for a discussion of amounts due from contracts with customers. Reserves for uncollectible accounts are recorded in selling, general and administrative expense in the Statements of Consolidated Operations. Judgment is required to assess the ultimate realization of the Company's accounts receivable. Reserves are based on historical experience, current and expected economic trends and specific information about customer accounts, such as the customer's creditworthiness. Derivative Instruments. See Note 4 for a discussion of the Company's derivative instruments and Note 5 for a description of the fair value hierarchy and a discussion of the Company's fair value measurements. Prepaid Expenses and Other. The following table summarizes the Company's prepaid expenses and other current assets.
| December 31,
| 2024 |  | 2023
| (Thousands)
Margin requirements with counterparties (see Note 4) | $ | 86,975 |  |  | $ | 13,017 |
Prepaid expenses and other current assets | 52,044 |  |  | 25,238 |
Total prepaid expenses and other | $ | 139,019 |  |  | $ | 38,255 |
Property, Plant and Equipment. The following table summarizes the Company's property, plant and equipment.
| December 31,
| 2024 |  | 2023
| (Thousands)
Oil and gas producing properties | $ | 33,549,913 |  |  | $ | 32,510,595 |
Less: Accumulated depletion | 12,489,317 |  |  | 10,734,099 |
Net oil and gas producing properties | 21,060,596 |  |  | 21,776,496 |
Other production assets, at cost less accumulated depreciation | 20,434 |  |  | 21,679 |
Net production assets | 21,081,030 |  |  | 21,798,175 |
Gathering assets | 8,067,556 |  |  | 1,153,049 |
Less: Accumulated depreciation | 131,546 |  |  | 41,793 |
Net gathering assets | 7,936,010 |  |  | 1,111,256 |
Transmission and storage assets | 2,667,352 |  |  | — |
Less: Accumulated depreciation | 30,027 |  |  | — |
Net transmission and storage assets | 2,637,325 |  |  | — |
Other property, plant and equipment, at cost less accumulated depreciation | 93,453 |  |  | 40,739 |
Net property, plant and equipment | $ | 31,747,818 |  |  | $ | 22,950,170 |
The Company uses the successful efforts method of accounting for gas, NGLs and oil producing activities. Under this method, the cost of productive wells and related equipment, development dry holes and productive acreage, including productive mineral interests, are capitalized and depleted using the unit-of-production method. These costs include salaries, benefits and other internal costs directly attributable to production activities. In 2024, 2023 and 2022, the Company capitalized internal costs of approximately $69 million, $57 million and $48 million, respectively, to its oil and gas producing properties. In addition, in 2024, 2023 and 2022, the Company capitalized interest expense related to well development of approximately $54 million, $41 million and $28 million, respectively. Depletion expense is calculated based on actual produced sales volume multiplied by the applicable depletion rate per unit. Depletion rates for leases and wells are each calculated by dividing net capitalized costs by the number of units expected to be produced over the life of the reserves separately. Costs for exploratory dry holes, exploratory geological and geophysical activities and delay rentals as well as other property carrying costs are charged to exploration expense. The Company's producing oil and gas properties had an overall average depletion rate of $0.90, $0.84 and $0.85 per Mcfe for the years ended December 31, 2024, 2023 and 2022, respectively. There were no exploratory wells drilled during 2024, 2023 and 2022, and there were no capitalized exploratory well costs for the years ended December 31, 2024, 2023 and 2022. The Company's gathering, transmission and storage property, plant and equipment is carried at cost. Maintenance projects that do not increase the overall life of the related assets are expensed as incurred. Expenditures that extend the useful life of the asset are capitalized. In 2024, the Company capitalized internal costs of approximately $25 million and $4 million to its gathering assets and transmission and storage assets, respectively. The Company's gathering, transmission and storage property, plant and equipment are depreciated using composite rates on a straight-line basis over the estimated useful life of the asset. The average depreciation rate for the year ended December 31, 2024 was 3.1%. Depreciation rates for the Company's regulated property, plant and equipment are reviewed when the Company files a change in transmission and storage rates with the FERC. Impairment of Property, Plant and Equipment Impairment of Proved Oil and Gas Properties. The carrying values of the Company's proved oil and gas properties are reviewed for impairment when events or circumstances indicate that the remaining carrying value may not be recoverable. To determine whether impairment of the Company's oil and gas properties has occurred, the Company compares the estimated expected undiscounted future cash flows to the carrying values of those properties. Estimated future cash flows are based on proved and, if determined reasonable by management, risk-adjusted probable reserves and assumptions generally consistent with the assumptions used by the Company for internal planning and budgeting purposes, including, among other things, the intended use of the asset, anticipated production from reserves, future market prices for natural gas, NGLs and oil adjusted for basis differentials, future operating costs and inflation. Proved oil and gas properties that have carrying amounts in excess of estimated future undiscounted cash flows are written down to fair value, which is estimated by discounting the estimated future cash flows using discount rates and other assumptions that marketplace participants would use in their fair value estimates. There were no indicators of impairment to the Company's material asset groups identified during 2024, 2023 and 2022. Impairment and Expiration of Leases. Capitalized costs of unproved oil and gas properties are evaluated for recoverability on a prospective basis at least annually. Indicators of potential impairment include changes due to economic factors, potential shifts in business strategy and historical experience. The likelihood of an impairment of unproved oil and gas properties increases as the expiration of a lease term approaches and drilling activity has not commenced. The Company recognizes impairment if the Company does not have the intent to drill on the leased property prior to expiration of the lease or does not have the intent and ability to extend, renew, trade or sell the lease prior to expiration. For the years ended December 31, 2024, 2023 and 2022, the Company recorded $97.4 million, $109.4 million and $176.6 million, respectively, for impairment and expiration of leases. The Company's unproved properties had a net book value of approximately $1,563 million and $2,039 million as of December 31, 2024 and 2023, respectively. Impairment of Other Property, Plant and Equipment. The Company evaluates its other property, plant and equipment for impairment when events or changes in circumstance indicate that the carrying value of such assets may not be recoverable. There were no indicators of impairment to the Company's asset groups identified during 2024, 2023 and 2022. Impairment of Contract Asset. In 2020, the Company recorded a contract asset representing rate relief that the Company was entitled to pursuant to a consolidated gas gathering and compression agreement (the Consolidated GGA) entered into between the Company and an affiliate of EQM Midstream Partners, LP (EQM), which became an indirect wholly-owned subsidiary of EQT upon the closing of the Equitrans Midstream Merger. During 2022, the Company identified indicators that the carrying amount of its contract asset might not be fully recoverable, including increased uncertainty of the estimated timing of completion of the Mountain Valley Pipeline (the MVP) due to court rulings and public statements from Equitrans Midstream Corporation (Equitrans Midstream), the former parent of EQM, with respect to the completion of the MVP. As a result of the Company's impairment evaluation, the Company recognized impairment of the contract asset of $214 million in the Statement of Consolidated Operations for the year ended December 31, 2022, decreasing the contract asset's value to zero. Investments in Unconsolidated Entities. See Note 11 for a discussion of the Company's investments in unconsolidated entities, which include EQT's equity method investments and investments in equity securities. The Company evaluates its investments in unconsolidated entities for impairment when events or changes in circumstances indicate that the investment's fair value is less than its carrying amount. The recognition of an impairment loss is required if the impairment is considered other than temporary. There were no indicators of impairment to the Company's investments in unconsolidated entities identified during 2024, 2023 and 2022. Net Intangible Assets. As part of the Equitrans Midstream Merger preliminary purchase price allocation, the Company identified intangible assets related to certain of Equitrans Midstream's transmission services contracts. See Note 6. The Company evaluates its intangible assets for impairment when indicators of impairment are present. There were no indicators of impairment to the Company's net intangible assets identified during 2024. Goodwill. Goodwill is the cost of an acquisition less the fair value of the identifiable net assets of the acquired business. Goodwill is allocated among, and evaluated for impairment at, the reporting unit level, which is defined as an operating segment or one level below an operating segment. The Company evaluates its goodwill for impairment at least annually or more frequently if indicators of impairment exist. Goodwill is tested for impairment by assessing qualitative factors to determine whether it is more likely than not (greater than 50%) that the fair value of the reporting unit is less than the carrying amount or by performing a quantitative assessment. If the qualitative assessment indicates a possible impairment, then a quantitative impairment test is performed to determine the fair value of the reporting unit using a combination of an income and market approach. Otherwise, no further analysis is required. Under the quantitative assessment, the evaluation of impairment involves comparing the current fair value of each reporting unit to its carrying value, including goodwill. In the event that the estimated fair value of a reporting unit is less than the carrying value, the Company would recognize an impairment loss equal to the excess of the reporting unit's carrying value over its fair value not to exceed the total amount of goodwill applicable to that reporting unit. The Company evaluated its goodwill for impairment as of October 1, 2024 and determined there were no indicators of impairment. Other Current Liabilities. The following table summarizes the Company's other current liabilities.
| December 31,
| 2024 |  | 2023
| (Thousands)
Accrued taxes other than income | $ | 114,700 |  |  | 62,391 |
Accrued incentive compensation | 53,138 |  |  | 24,542 |
Current portion of long-term capacity contracts | 43,697 |  |  | 43,233 |
Current portion of lease liabilities | 41,878 |  |  | 46,380 |
Deferred revenue | 24,187 |  |  | 2,890 |
Accrued payroll | 12,115 |  |  | 8,870 |
Other accrued liabilities | 59,702 |  |  | 16,697 |
Total other current liabilities | $ | 349,417 |  |  | $ | 205,003 |
Unamortized Debt Discount and Issuance Costs. Discounts and costs incurred with the issuance of debt are amortized over the life of the debt. These amounts are presented as a reduction of debt in the Consolidated Balance Sheets. See Note 10. Leases. See Note 14 for a discussion of the Company's leases. Income Taxes. The Company files a consolidated U.S. federal income tax return and uses the asset and liability method to account for income taxes. The provision for income taxes represents amounts paid or estimated to be payable net of amounts refunded or estimated to be refunded for the current year and the change in deferred taxes exclusive of amounts recorded in other comprehensive loss. Any refinements to prior year taxes made in the current year due to new information are reflected as adjustments in the current period. Separate income taxes are calculated for items charged or credited directly to shareholders' equity. EQM, Eureka Midstream Holdings and the Midstream Joint Venture are treated as partnerships for U.S. federal and applicable state income tax purposes and are not separately subject to U.S. federal or state income taxes. EQM's, Eureka Midstream Holdings' and the Midstream Joint Venture's income is included in the Company's pre-tax income; however, the Company does not record income tax expense on income attributable to noncontrolling interests in Eureka Midstream Holdings and the Midstream Joint Venture, which reduces the Company's effective tax rate in periods when the Company has consolidated pre-tax income and increases the effective tax rate in periods when the Company has consolidated pre-tax losses. Deferred tax assets and liabilities arise from temporary differences between the financial reporting and tax bases of the Company's assets and liabilities and are recognized using enacted tax rates for the effect of such temporary differences. Deferred tax assets are reduced by a valuation allowance if it is more likely than not that a portion or all of the deferred tax asset will not be realized. When evaluating whether or not a valuation allowance should be established, the Company exercises judgment on whether it is more likely than not (a likelihood of more than 50%) that a portion or all of the deferred tax assets will not be realized. To determine whether a valuation allowance is needed, the Company considers all available evidence, both positive and negative, including carrybacks, tax planning strategies, reversals of deferred tax assets and liabilities and forecasted future taxable income. In accounting for uncertainty of a tax position taken or expected to be taken in a tax return, the Company uses a recognition threshold and measurement attribute for the financial statement recognition and measurement. The recognition threshold requires the Company to determine whether it is more likely than not that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes, based on the technical merits of the position. If it is more likely than not that a tax position will be sustained, the Company measures and recognizes the tax position at the largest amount of benefit that has a greater than 50% likelihood of being realized upon ultimate settlement. To determine the amount of financial statement benefit recorded for uncertain tax positions, the Company considers the amounts and probabilities of outcomes that could be realized upon ultimate settlement of an uncertain tax position using facts, circumstances and information available at the reporting date. The Company recognizes accrued interest and penalties related to unrecognized tax benefits in income tax expense. See Note 9. Insurance. The Company maintains insurance to cover traditional insurable risks such as general liability, workers compensation, auto liability, environmental liability, property damage, business interruption, fiduciary liability, director and officers' liability and other risks. These policies may be subject to deductible or retention amounts, coverage limitations and exclusions. The Company was previously self-insured for certain material losses related to general liability, workers compensation and environmental liability; however, the Company now maintains insurance for such losses arising on or after November 12, 2020. In addition, in conjunction with the Equitrans Midstream Merger, the Company assumed a self-insured retention reserve for certain material losses related to excess liability and environmental liability for losses arising before December 20, 2024. The Company also assumed with the Equitrans Midstream Merger a 10% co-insurance related to material losses on property insurance coverage. Prospectively, coverage is included in the Company's insurance programs that do not have high self-insured and co-insurance amounts. Reserves are recorded on an undiscounted basis using analyses of historical data and, where applicable, actuarial estimates, which represent estimates of the ultimate cost of claims incurred as of the balance sheet date. The reserves are reviewed by the Company quarterly and, where applicable, by independent actuaries annually. Asset Retirement Obligations. The Company accrues a liability for asset retirement obligations based on an estimate of the amount and timing of settlement. For oil and gas wells, the fair value of the Company's plugging and abandonment obligations is recorded at the time the obligation is incurred, which is typically at the time the well is spud. Upon initial recognition of an asset retirement obligation, the Company increases the carrying amount of the long-lived asset by the same amount as the liability. Over time, the liabilities are accreted for the change in their present value through charges to depreciation and depletion expense. The initial capitalized costs are depleted over the useful lives of the related assets. The Company's asset retirement obligations related to the abandonment of oil and gas producing facilities include reclaiming well pads, reclaiming water impoundments, plugging wells and dismantling related structures. In addition, the Company records asset retirement obligations on its storage wells with known plugging timelines. Estimates are based on historical experience of plugging and abandoning wells and reclaiming or disposing other assets and estimated remaining lives of the wells and assets. The Company is under no legal or contractual obligation to restore or dismantle its gathering and transmission pipeline assets upon abandonment. In addition, the Company is responsible for the operation and maintenance of its gathering and transmission assets and intends to continue such operation and maintenance so long as supply and demand for natural gas exists. As the Company expects supply and demand for natural gas to exist into the foreseeable future, the Company has not recorded asset retirement obligations for its gathering and transmission pipeline assets. The following table presents a reconciliation of the beginning and ending carrying amounts of the Company's asset retirement obligations included in other liabilities and credits in the Consolidated Balance Sheets.
| December 31,
| 2024 |  | 2023
| (Thousands)
Balance at January 1 | $ | 911,057 |  |  | $ | 732,803 |
Accretion expense | 68,501 |  |  | 47,700 |
Liabilities incurred | 21,587 |  |  | 10,515 |
Liabilities settled | (66,729) |  |  | (33,938) |
Liabilities assumed in acquisitions | 45,847 |  |  | 64,424 |
Liabilities removed in divestitures | (28,701) |  |  | (6,480) |
Change in estimates (a) | 52,008 |  |  | 96,033 |
Balance at December 31 | $ | 1,003,570 |  |  | $ | 911,057 |
(a)During 2024, the Company recorded changes in estimates attributable primarily to increased plugging costs. During 2023, the Company recorded changes in estimates attributable primarily to inflation on estimated plugging costs. The Company does not have assets that are legally restricted for purposes of settling its asset retirement obligations. The Company operates in several states that have implemented expanded requirements for settling asset retirement obligations. This has resulted in the Company's use of additional materials during the plugging process, which has increased the estimated cost for plugging horizontal and conventional wells. Regulatory Accounting. As of December 31, 2024, the Company consolidates the Midstream Joint Venture, which holds Equitrans, L.P., which owns and operates the Midstream Joint Venture's wholly-owned FERC-regulated transmission and storage assets. Through the rate-setting process, rate regulation allows recovery of costs to provide regulated services plus an allowed return on invested capital. Regulatory accounting allows deferral of costs and income as regulated assets and liabilities when it is probable that such costs and income is subject to recovery in future periods. Such deferred amounts are then recognized in Equitrans, L.P.'s Statement of Operations in the period in which the underlying costs and income are reflected in the rates charged by Equitrans, L.P. to shippers and operators. Equitrans, L.P. expects to continue to be subject to rate regulation. The following table presents Equitrans, L.P.'s regulated operating revenues and expenses included in the Company's Consolidated Statement of Operations for the period from July 22, 2024 to December 31, 2024.
| July 22, 2024 to December 31, 2024
| (Thousands)
Operating revenues | $ | 218,569 |  |  |
Operating expenses | $ | 78,908 |  |  |
The following table presents Equitrans, L.P.'s regulated property, plant and equipment included in the Company's Consolidated Balance Sheet as of December 31, 2024.
| December 31, 2024
| (Thousands)
Property, plant and equipment | $ | 2,667,352 |  |  |
Less: Accumulated depreciation | 30,027 |  |  |
Net property, plant and equipment | $ | 2,637,325 |  |  |
The Company includes Equitrans, L.P.'s regulated assets and liabilities in its Consolidated Balance Sheet. Equitrans, L.P.'s regulated assets are reported in other assets, and Equitrans, L.P.'s regulated liabilities are reported in other liabilities and credits. The following table summarizes Equitrans, L.P.'s regulated assets and liabilities as of December 31, 2024.
| December 31, 2024
| (Thousands)
Regulated assets: |  |  |
Deferred taxes (a) | $ | 142,757 |  |  |
Other recoverable costs (b) | 23,182 |  |  |
Total regulated assets | $ | 165,939 |  |  |
Regulated liabilities: |  |  |
Deferred taxes (a) | $ | 8,534 |  |  |
Ongoing postretirement benefits other than pension and other reimbursable costs (c) | 20,158 |  |  |
Total regulated liabilities | $ | 28,692 |  |  |
(a)The regulated asset from deferred taxes is related primarily to a historical deferred income tax position as well as taxes on the equity component of allowance for funds used during construction (AFUDC). The regulated liability from deferred taxes is related to the revaluation of a historical difference between the regulatory and tax bases of regulated property, plant and equipment. Equitrans, L.P. expects to recover the amortization of the deferred income tax positions ratably over the depreciable lives of the underlying assets. In addition, Equitrans, L.P. expects to recover the taxes on the equity component of AFUDC through future rates over the depreciable lives of the underlying long-lived assets. (b)The regulated asset from other recoverable costs is related primarily to costs associated with Equitrans, L.P.'s asset retirement obligations, which Equitrans, L.P. expects to continue to recover over the next 9.5 years, and costs associated with a legacy postretirement benefits plan, which Equitrans, L.P. expects to continue to recover over the next 7.5 years. (c)Equitrans, L.P. defers costs for other postretirement benefits plans, which are subject to recovery in approved rates. The related regulated liability reflects lower cumulative actuarial expenses than the amounts recovered through rates. Equitrans, L.P. expects to continue to recover costs as long as the existing recourse rates provide for recovery. Revenue Recognition. For information on revenue recognition from contracts with customers, see Note 3. For information on gains and losses on derivative commodity instruments, see Note 4. Transportation and Processing. Costs incurred to gather, process and transport gas produced by the Company to market sales points are recorded as transportation and processing costs in the Statements of Consolidated Operations. The Company markets some transportation for resale. These costs, which are not incurred to transport gas produced by the Company, are reflected as a deduction from net marketing services and other revenues. Share-based Compensation. See Note 13 for a discussion of the Company's share-based compensation plans. Other Operating Expenses. The following table summarizes the Company's other operating expenses.
| Years Ended December 31,
| 2024 |  | 2023 |  | 2022
| (Thousands)
Transaction costs | $ | 309,419 |  |  | $ | 56,263 |  |  | $ | 14,185 |
Changes in legal and environmental reserves, including settlements | 16,271 |  |  | 9,342 |  |  | $ | 30,394 |
Other | 24,174 |  |  | 18,438 |  |  | 12,752 |
Total other operating expenses | $ | 349,864 |  |  | $ | 84,043 |  |  | $ | 57,331 |
Defined Contribution Plan and Other Postretirement Benefits Plan. The Company recognized expense related to its defined contribution plan of $14.5 million, $9.0 million and $7.8 million for the years ended December 31, 2024, 2023 and 2022, respectively. In addition, the Company sponsors an other postretirement benefits plan. Income Per Share. See Note 12 for a discussion of the Company's common stock and income per share computation. Supplemental Cash Flow Information. The following table summarizes net cash paid for interest and income taxes and non-cash activity included in the Statements of Consolidated Cash Flows.
| Years Ended December 31,
| 2024 |  | 2023 |  | 2022
| (Thousands)
Cash paid during the year for: |  |  |  |  |
Interest, net of amount capitalized | $ | 401,768 |  |  | $ | 213,141 |  |  | $ | 236,797 |
Income taxes, net | 7,960 |  |  | 13,350 |  |  | 20,773 |
Non-cash activity during the period for: |  |  |  |  |
Equity issued as consideration for acquisitions (Note 6) | $ | 5,548,608 |  |  | $ | 2,152,631 |  |  | $ | — |
Issuance of EQT common stock for Convertible Notes settlement (Note 10) | 285,608 |  |  | 122,830 |  |  | 63 |
First NEPA Non-Operated Asset Divestiture (Note 7) | 155,318 |  |  | — |  |  | — |
Increase in asset retirement costs and obligations | 73,576 |  |  | 106,548 |  |  | 54,608 |
Increase in right-of-use assets and lease liabilities, net | 29,568 |  |  | 45,774 |  |  | 23,356 |
Capitalization of non-cash equity share-based compensation | 10,095 |  |  | 6,287 |  |  | 5,406 |
Investments in nonconsolidated entities | 3,428 |  |  | — |  |  | — |
Accrued transaction costs related to the sale of units of the Midstream Joint Venture (Note 8) | 1,135 |  |  | — |  |  | — |
Dissolution of consolidated variable interest entity | — |  |  | 25,227 |  |  | — |
Recently Issued Accounting Standards In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures, to improve reportable segment disclosure requirements, primarily through the requirement of enhanced disclosure of significant segment expenses. In addition, this ASU enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss and provides new segment disclosure requirements for entities with a single reportable segment. This ASU is effective for annual reporting periods beginning after December 15, 2023 and interim periods within annual reporting periods beginning after December 15, 2024. The Company adopted ASU 2023-07 in the fourth quarter of 2024. See Note 2 for segments disclosures. In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures, to improve income tax disclosure requirements. Under this ASU, public business entities must annually (1) disclose specific categories in the rate reconciliation and (2) provide additional information for reconciling items that meet a quantitative threshold. This ASU is effective for annual reporting periods beginning after December 15, 2024, and early adoption is permitted. The Company does not expect adoption of ASU 2023-09 to have a material impact on its financial statements and related disclosures. In November 2024, the FASB issued ASU 2024-03, Disaggregation of Income Statement Expenses, to improve the disclosures about a public business entity's expenses and address requests from investors for more detailed information about the types of expenses (including purchases of inventory, employee compensation, depreciation, amortization and depletion) in commonly presented expense captions (such as cost of sales; selling, general and administrative expense; and research and development). This ASU is effective for annual reporting periods beginning after December 15, 2026 and interim reporting periods beginning after December 15, 2027. Early adoption is permitted. The requirements should be applied prospectively with the option for retrospective application. The Company is evaluating the impact ASU 2024-03 will have on its financial statements and related disclosures. Subsequent Events. The Company has evaluated subsequent events through the date of the financial statement issuance.

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