Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of financial condition and results of operations should be read in conjunction with the Condensed Consolidated Financial Statements and the notes thereto included in this report. Unless the context otherwise indicates, all references in this report to "EQT," the "Company," "we," "us," or "our" are to EQT Corporation and its consolidated subsidiaries, collectively. For certain industry specific terms used in this Quarterly Report on Form 10-Q, please see "Glossary of Commonly Used Terms, Abbreviations and Measurements" in our Annual Report on Form 10-K for the year ended December 31, 2023.

CAUTIONARY STATEMENTS

This Quarterly Report on Form 10-Q contains certain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and Section 27A of the Securities Act of 1933, as amended (the Securities Act). Statements that do not relate strictly to historical or current facts are forward-looking and are usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe" and other words of similar meaning, or the negative thereof. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the matters discussed in the section "Trends and Uncertainties" and expectations of our plans, strategies, objectives and growth and anticipated financial and operational performance, including guidance regarding our strategy to develop our reserves; drilling plans and programs, including availability of capital to complete these plans and programs; total resource potential and drilling inventory duration; projected production and sales volume, including liquified natural gas (LNG) volumes and sales; natural gas prices; changes in basis and the impact of commodity prices on our business; potential future impairments of our assets; projected well costs and capital expenditures; infrastructure programs; the cost, capacity and timing of obtaining regulatory approvals; our ability to successfully implement and execute our operational, organizational, technological and environmental, social and governance (ESG) initiatives, and achieve the anticipated results of such initiatives; projected gathering and compression rates; potential acquisitions or other strategic transactions, the timing thereof and our ability to achieve the intended operational, financial and strategic benefits from any such transactions or from any recently completed strategic transactions, including the Equitrans Midstream Merger (defined and discussed in Note 10 to the Condensed Consolidated Financial Statements); the amount and timing of any repayments, redemptions or repurchases of our common stock, outstanding debt securities or other debt instruments; our ability to retire our debt and the timing of such retirements, if any; the projected amount and timing of dividends; projected cash flows and free cash flow, and the timing thereof; liquidity and financing requirements, including funding sources and availability; our ability to maintain or improve our credit ratings, leverage levels and financial profile; our hedging strategy and projected margin posting obligations; the effects of litigation, government regulation and tax position; and the expected impact of changes to tax laws.

The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. We have based these forward-looking statements on current expectations and assumptions about future events, taking into account all information currently known by us. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks and uncertainties, many of which are difficult to predict and beyond our control. These risks and uncertainties include, but are not limited to, volatility of commodity prices; the costs and results of drilling and operations; uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future; the assumptions underlying production forecasts; the quality of technical data; our ability to appropriately allocate capital and other resources among our strategic opportunities; access to and cost of capital, including as a result of rising interest rates and other economic uncertainties; our hedging and other financial contracts; inherent hazards and risks normally incidental to drilling for, producing, transporting and storing natural gas, natural gas liquids (NGLs) and oil; cyber security risks and acts of sabotage; availability and cost of drilling rigs, completion services, equipment, supplies, personnel, oilfield services and sand and water required to execute our exploration and development plans, including as a result of inflationary pressures; risks associated with operating primarily in the Appalachian Basin; the ability to obtain environmental and other permits and the timing thereof; government regulation or action, including regulations pertaining to methane and other greenhouse gas emissions; negative public perception of the fossil fuels industry; increased consumer demand for alternatives to natural gas; environmental and weather risks, including the possible impacts of climate change; risks related to our ability to integrate the operations of Equitrans Midstream Corporation (Equitrans Midstream) in a successful manner and in the expected time period and the possibility that any of the anticipated benefits and projected synergies of the Equitrans Midstream Merger will not be realized or will not be realized within the expected time period; and disruptions to our business due to recently completed acquisitions and other significant transactions, including the Equitrans Midstream Merger. These and other risks and uncertainties are described under the "Risk Factors" section in this

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Quarterly Report on Form 10-Q and under the "Risk Factors" section and elsewhere in our Annual Report on Form 10-K for the year ended December 31, 2023, and may be updated by the "Risk Factors" section of subsequent Quarterly Reports on Form 10-Q and other documents we subsequently file from time to time with the Securities and Exchange Commission.

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by law, we do not intend to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Consolidated Results of Operations

Net income attributable to EQT Corporation for the three months ended June 30, 2024 was $9.5 million, $0.02 per diluted share, compared to net loss attributable to EQT Corporation of $66.6 million, $0.18 per diluted share, for the same period in 2023. The change was attributable primarily to the gain on the NEPA Non-Operated Asset Divestiture (defined in Note 9 to the Condensed Consolidated Financial Statements) and increased sales of natural gas, NGLs and oil, partly offset by a lower gain on derivatives, increased depreciation and depletion expense and increased production expense.

Net income attributable to EQT Corporation for the six months ended June 30, 2024 was $113.0 million, $0.25 per diluted share, compared to $1,151.9 million, $2.94 per diluted share, for the same period in 2023. The decrease was attributable primarily to a lower gain on derivatives, decreased sales of natural gas, NGLs and oil, increased depreciation and depletion expense and increased production expense, partly offset by an income tax benefit in 2024 compared to income tax expense in 2023 as well as the gain on the NEPA Non-Operated Asset Divestiture.

Results of operations for 2024 include the results of our operation of assets acquired in the Tug Hill and XcL Midstream Acquisition (defined in Note 9 to the Condensed Consolidated Financial Statements), which closed on August 22, 2023. In addition, results of operations for 2024 include the results of our operation of assets received as consideration for the NEPA Non-Operated Asset Divestiture, which closed on May 31, 2024. Such assets received included the remaining 16.25% equity interest in the NEPA Gathering System (defined in Note 9 to the Condensed Consolidated Financial Statements) (which was the sole remaining minority interest following our acquisition of a 33.75% equity interest in the NEPA Gathering System Acquisition on April 11, 2024), resulting in our 100% ownership of the NEPA Gathering System. See Note 9 to the Condensed Consolidated Financial Statements.

See "Sales Volume and Revenues" and "Operating Expenses" for discussions of items affecting operating income and "Other Income Statement Items" for a discussion of other income statement items. See "Investing Activities" under "Capital Resources and Liquidity" for a discussion of capital expenditures.

Recent Events

On July 22, 2024, we completed the Equitrans Midstream Merger pursuant to the Merger Agreement (defined in Note 10 to the Condensed Consolidated Financial Statements).

Upon closing of the Equitrans Midstream Merger, each share of common stock, no par value, of Equitrans Midstream (Equitrans Midstream common stock) that was issued and outstanding immediately prior to the effective time of the First Merger (defined in Note 10 to the Condensed Consolidated Financial Statements) (other than shares of Equitrans Midstream common stock owned by Equitrans Midstream or its subsidiaries or by us) was converted into the right to receive, without interest, 0.3504 shares of EQT Corporation common stock, with cash in lieu of fractional shares. As a result of the Equitrans Midstream Merger, we acquired over 2,000 miles of pipeline infrastructure that have extensive overlap and connectivity in our core area of operations and we became the first large-scale, integrated natural gas producer in the United States. See Note 10 to the Condensed Consolidated Financial Statements.

Trends and Uncertainties

Following receipt of authorization from the Federal Energy Regulatory Commission, the Mountain Valley Pipeline entered into service on June 14, 2024. Upon commencement of long-term firm capacity obligations, the MVP In-Service Date (as defined within the Consolidated GGA (defined in Note 3 to the Condensed Consolidated Financial Statements)) occurred on July 1, 2024. We are committed to an initial 1.29 Bcf per day of firm capacity on the Mountain Valley Pipeline through June 30, 2044. Accordingly, as a result of the Mountain Valley Pipeline commencing full service, we expect our future transmission expense to increase as a result of the additional contracted capacity and our future gathering cost structure pursuant to the Consolidated GGA to further decrease.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

On March 4, 2024, we announced our decision to strategically curtail approximately 1.0 Bcf per day of gross production (the Strategic Curtailment) beginning on February 24, 2024 in response to the low natural gas price environment resulting from warm winter weather and elevated storage inventories. The Strategic Curtailment resulted in total decreased sales volume of 82 Bcfe during the period beginning on February 24, 2024 through June 19, 2024, of which decreases of 54 Bcfe occurred during the second quarter of 2024. In response to market fundamentals, we may continue to strategically curtail our production. Our sales volume guidance for the second half of 2024 assumes additional strategic curtailments of approximately 90 Bcfe of net production.

Continued low natural gas prices may result in further adjustment to our 2024 planned development schedule or the development schedule of non-operated wells in which we have a working interest. Further, we cannot control or otherwise influence the development schedule of non-operated wells in which we have a working interest. Certain operators of wells in which we have a non-operating working interest also curtailed production in the first half of 2024. Inclusive of the Strategic Curtailment of 82 Bcfe, we estimate that total expected sales volume was negatively impacted by approximately 90 to 95 Bcfe of curtailments during the first half of 2024, the total of which includes curtailments by certain operators of wells in which we have a non-operating working interest. Adjustments to our 2024 planned development schedule or the development schedule of non-operated wells in which we have a working interest, including due to declines in natural gas prices, the pace of well completions, access to sand and water to conduct drilling operations, access to sufficient pipeline takeaway capacity, unscheduled downtime at processing facilities or otherwise, could impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.

The annual inflation rate in the United States remains elevated compared to the rate of inflation over the prior five years. Inflationary pressures have multiple impacts on our business, including increasing our operating expenses and our cost of capital. While the prices for certain of the raw materials and services we use in our operations have generally decreased from the peak prices experienced during 2022, we will not fully realize the benefit of such reduced prices until we enter into new contracts for such materials and services, and inflationary pressures may cause prices to fluctuate. Additionally, certain of our commitments for demand charges under our existing long-term contracts and processing capacity are subject to consumer price index adjustments. Although we believe our scale and supply chain contracting strategy of using multi-year sand and frac crew contracts allows us to maximize capital and operating efficiencies, future increases in the inflation rate will negatively impact our long-term contracts with consumer price index adjustments.

We expect commodity prices to be volatile throughout 2024 due to macroeconomic uncertainty and geopolitical tensions, including developments pertaining to Russia's invasion of Ukraine and conflicts in the Middle East. Our revenue, profitability, liquidity and financial position will continue to be impacted in the future by the market prices for natural gas and, to a lesser extent, NGLs and oil.

Average Realized Price Reconciliation

The following table presents detailed natural gas and liquids operational information to assist in the understanding of our consolidated operations, including the calculation of our average realized price ($/Mcfe), which is based on adjusted operating revenues, a non-GAAP supplemental financial measure. Adjusted operating revenues is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Adjusted operating revenues should not be considered as an alternative to total operating revenues. See "Non-GAAP Financial Measures Reconciliation" for a reconciliation of adjusted operating revenues with total operating revenues, the most directly comparable financial measure calculated in accordance with United States generally accepted accounting principles (GAAP).

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

			Three Months Ended June 30,												Six Months Ended June 30,
			2024						2023						2024						2023
			(Thousands, unless otherwise noted)
NATURAL GAS
Sales volume (MMcf)			474,075						449,658						973,349						883,055
NYMEX price ($/MMBtu)			$	1.92					$	2.10					$	2.09					$	2.76
Btu uplift			0.10						0.10						0.12						0.14
Natural gas price ($/Mcf)			$	2.02					$	2.20					$	2.21					$	2.90
Basis ($/Mcf) (a)			$	(0.49)					$	(0.50)					$	(0.31)					$	(0.10)
Cash settled basis swaps ($/Mcf)			(0.19)						(0.20)						(0.11)						(0.18)
Average differential, including cash settled basis swaps ($/Mcf)			$	(0.68)					$	(0.70)					$	(0.42)					$	(0.28)
Average adjusted price ($/Mcf)			$	1.34					$	1.50					$	1.79					$	2.62
Cash settled derivatives ($/Mcf)			0.82						0.53						0.84						0.42
Average natural gas price, including cash settled derivatives ($/Mcf)			$	2.16					$	2.03					$	2.63					$	3.04
Natural gas sales, including cash settled derivatives			$	1,025,694					$	912,966					$	2,563,560					$	2,688,101
LIQUIDS
NGLs, excluding ethane:
Sales volume (MMcfe) (b)			20,408						11,679						41,140						25,176
Sales volume (Mbbl)			3,401						1,946						6,856						4,196
NGLs price ($/Bbl)			$	37.95					$	31.28					$	39.78					$	35.29
Cash settled derivatives ($/Bbl)			(0.51)						(1.21)						(0.25)						(1.83)
Average NGLs price, including cash settled derivatives ($/Bbl)			$	37.44					$	30.07					$	39.53					$	33.46
NGLs sales, including cash settled derivatives			$	127,361					$	58,533					$	271,092					$	140,389
Ethane:
Sales volume (MMcfe) (b)			11,182						7,743						22,552						17,670
Sales volume (Mbbl)			1,864						1,291						3,759						2,945
Ethane price ($/Bbl)			$	5.71					$	5.43					$	6.15					$	6.34
Ethane sales			$	10,640					$	7,008					$	23,102					$	18,660
Oil:
Sales volume (MMcfe) (b)			1,847						1,759						4,521						3,743
Sales volume (Mbbl)			308						293						754						624
Oil price ($/Bbl)			$	61.96					$	49.71					$	60.06					$	54.30
Oil sales			$	19,078					$	14,570					$	45,259					$	33,868
Total liquids sales volume (MMcfe) (b)			33,437						21,181						68,213						46,589
Total liquids sales volume (Mbbl)			5,573						3,530						11,369						7,765
Total liquids sales			$	157,079					$	80,111					$	339,453					$	192,917
TOTAL
Total natural gas and liquids sales, including cash settled derivatives (c)			$	1,182,773					$	993,077					$	2,903,013					$	2,881,018
Total sales volume (MMcfe)			507,512						470,839						1,041,562						929,644
Average realized price ($/Mcfe)			$	2.33					$	2.11					$	2.79					$	3.10

(a)Basis represents the difference between the ultimate sales price for natural gas, including the effects of delivered price benefit or deficit associated with our firm transportation agreements, and the New York Mercantile Exchange (NYMEX) natural gas price.

(b)NGLs, ethane and oil were converted to Mcfe at a rate of six Mcfe per barrel.

(c)Total natural gas and liquids sales, including cash settled derivatives, is also referred to in this report as adjusted operating revenues, a non-GAAP supplemental financial measure.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Non-GAAP Financial Measures Reconciliation

The table below reconciles adjusted operating revenues, a non-GAAP supplemental financial measure, with total operating revenues, its most directly comparable financial measure calculated in accordance with GAAP. Adjusted operating revenues (also referred to in this report as total natural gas and liquids sales, including cash settled derivatives) is presented because it is an important measure we use to evaluate period-to-period comparisons of earnings trends. Adjusted operating revenues excludes the revenue impacts of changes in the fair value of derivative instruments prior to settlement and net marketing services and other. We use adjusted operating revenues to evaluate earnings trends because, as a result of the measure's exclusion of the often-volatile changes in the fair value of derivative instruments prior to settlement, the measure reflects only the impact of settled derivative contracts. Net marketing services and other consists of the costs of, and recoveries on, pipeline capacity releases, revenues for gathering and processing services provided to third parties and other revenues. Because we consider net marketing services and other to be unrelated to our natural gas and liquids production activities, adjusted operating revenues excludes net marketing services and other. We believe that adjusted operating revenues provides useful information to investors for evaluating period-to-period comparisons of earnings trends.

			Three Months Ended June 30,												Six Months Ended June 30,
			2024						2023						2024						2023
			(Thousands, unless otherwise noted)
Total operating revenues			$	952,512					$	1,018,751					$	2,364,780					$	3,679,822
(Deduct) add:
Gain on derivatives			(61,333)						(164,386)						(167,844)						(989,238)
Net cash settlements received on derivatives			298,181						212,247						749,185						369,247
Premiums paid for derivatives that settled during the period			(4,925)						(67,495)						(39,594)						(166,912)
Net marketing services and other			(1,662)						(6,040)						(3,514)						(11,901)
Adjusted operating revenues, a non-GAAP financial measure			$	1,182,773					$	993,077					$	2,903,013					$	2,881,018
Total sales volume (MMcfe)			507,512						470,839						1,041,562						929,644
Average realized price ($/Mcfe)			$	2.33					$	2.11					$	2.79					$	3.10

Sales Volume and Revenues

Three Months Ended June 30, 2024 Compared to Three Months Ended June 30, 2023

			Three Months Ended June 30,
			2024						2023						Change						% Change
			(Thousands, unless otherwise noted)
Total sales volume (MMcfe)			507,512						470,839						36,673						7.8
Average daily sales volume (MMcfe/d)			5,577						5,174						403						7.8
Operating revenues:
Sales of natural gas, NGLs and oil			$	889,517					$	848,325					$	41,192					4.9
Gain on derivatives			61,333						164,386						(103,053)						(62.7)
Net marketing services and other			1,662						6,040						(4,378)						(72.5)
Total operating revenues			$	952,512					$	1,018,751					$	(66,239)					(6.5)

Sales volume. Sales volume increased for the three months ended June 30, 2024 compared to the same period in 2023 primarily as a result of sales volume increases of 58 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition and from wells turned-in-line throughout 2023 and in the first half of 2024, partly offset by sales volume decreases of 54 Bcfe due to the Strategic Curtailment.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil increased for the three months ended June 30, 2024 compared to the same period in 2023 due to higher average realized price and increased sales volume.

Average realized price increased for the three months ended June 30, 2024 compared to the same period in 2023 due to favorable cash settled NYMEX derivatives and higher NGLs prices, partly offset by lower NYMEX prices. The following table presents the composition of net cash settlements received on derivatives.

			Three Months Ended June 30,
			2024						2023
			(Thousands)
Net cash settlements received on NYMEX natural gas hedge positions			$	391,867					$	304,827
Net cash settlements paid on basis and liquids hedge positions			(93,686)						(92,580)
Net cash settlements received on derivatives			$	298,181					$	212,247

Net cash settlements received on derivatives are included in average realized price but may not be included in operating revenues.

For the three months ended June 30, 2024 and 2023, we paid premiums of $4.9 million and $67.5 million, respectively, for derivatives that settled during the period.

Gain on derivatives. For the three months ended June 30, 2024, we recognized a gain on derivatives of $61.3 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices. For the three months ended June 30, 2023, we recognized a gain on derivatives of $164.4 million related primarily to increases in the fair market value of our basis swaps, which was in a liability position as of March 31, 2023, partly offset by a loss on the derivative liability related to the Henry Hub Cash Bonus (defined and discussed in Note 4 to the Condensed Consolidated Financial Statements).

Six Months Ended June 30, 2024 Compared to Six Months Ended June 30, 2023

			Six Months Ended June 30,
			2024						2023						Change						% Change
			(Thousands, unless otherwise noted)
Total sales volume (MMcfe)			1,041,562						929,644						111,918						12.0
Average daily sales volume (MMcfe/d)			5,723						5,136						587						11.4
Operating revenues:
Sales of natural gas, NGLs and oil			$	2,193,422					$	2,678,683					$	(485,261)					(18.1)
Gain on derivatives			167,844						989,238						(821,394)						(83.0)
Net marketing services and other			3,514						11,901						(8,387)						(70.5)
Total operating revenues			$	2,364,780					$	3,679,822					$	(1,315,042)					(35.7)

Sales volume. Sales volume increased for the six months ended June 30, 2024 compared to the same period in 2023 primarily as a result of sales volume increases of 124 Bcfe from the assets acquired in the Tug Hill and XcL Midstream Acquisition and increases from wells turned-in-line throughout 2023 and in the first half of 2024, partly offset by sales volume decreases of 82 Bcfe due to the Strategic Curtailment.

Sales of natural gas, NGLs and oil. Sales of natural gas, NGLs and oil decreased for the six months ended June 30, 2024 compared to the same period in 2023 due to lower average realized price, partly offset by increased sales volume.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Average realized price decreased for the six months ended June 30, 2024 compared to the same period in 2023 due to lower NYMEX prices and lower East Coast basis spreads, partly offset by favorable cash settled NYMEX derivatives and higher NGLs prices. The following table presents the composition of net cash settlements received on derivatives.

			Six Months Ended June 30,
			2024						2023
			(Thousands)
Net cash settlements received on NYMEX natural gas hedge positions			$	856,128					$	539,005
Net cash settlements paid on basis and liquids hedge positions			(106,943)						(169,758)
Net cash settlements received on derivatives			$	749,185					$	369,247

Net cash settlements received on derivatives are included in average realized price but may not be included in operating revenues.

For the six months ended June 30, 2024 and 2023, we paid premiums of $39.6 million and $166.9 million, respectively, for derivatives that settled during the period.

Gain on derivatives. For the six months ended June 30, 2024, we recognized a gain on derivatives of $167.8 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices. For the six months ended June 30, 2023, we recognized a gain on derivatives of $989.2 million related primarily to increases in the fair market value of our NYMEX swaps and options due to decreases in NYMEX forward prices, partly offset by a loss on the derivative liability related to the Henry Hub Cash Bonus.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Operating Expenses

Three Months Ended June 30, 2024 Compared to Three Months Ended June 30, 2023

			Three Months Ended June 30,
			2024						2023						Change						% Change
			(Thousands, unless otherwise noted)
Operating expenses:
Gathering			$	297,307					$	318,491					$	(21,184)					(6.7)
Transmission			178,354						153,152						25,202						16.5
Processing			67,406						51,519						15,887						30.8
Lease operating expense (LOE)			59,103						35,552						23,551						66.2
Production taxes			43,084						19,486						23,598						121.1
Exploration			1,378						1,203						175						14.5
Selling, general and administrative			67,207						60,163						7,044						11.7
Production depletion			$	455,778					$	390,504					$	65,274					16.7
Other depreciation and depletion			10,204						5,180						5,024						97.0
Total depreciation and depletion			$	465,982					$	395,684					$	70,298					17.8
Per Unit ($/Mcfe):
Gathering			$	0.59					$	0.68					$	(0.09)					(13.2)
Transmission			0.35						0.33						0.02						6.1
Processing			0.13						0.11						0.02						18.2
LOE			0.12						0.08						0.04						50.0
Production taxes			0.08						0.04						0.04						100.0
Selling, general and administrative			0.13						0.13						—						—
Production depletion			0.90						0.83						0.07						8.4

Gathering. Gathering expense decreased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to the lower gathering cost structure that resulted pursuant to the Consolidated GGA as well as from our acquisition of the remaining minority interest in the NEPA Gathering System during the second quarter of 2024. In addition, gathering expense per Mcfe for the three months ended June 30, 2024 compared to the same period in 2023 benefited from our ownership of the gathering assets acquired in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023.

Transmission. Transmission expense increased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to credits received from the Texas Eastern Transmission Pipeline in 2023 as well as additional capacity acquired.

Processing. Processing expense increased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to increased processing expense from the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition.

LOE. LOE increased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to increased LOE from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to increased West Virginia property tax expense from the assets acquired in the Tug Hill and XcL Midstream Acquisition and higher price as well as increased severance tax expense from increased volumes from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Selling, general and administrative. Selling, general and administrative expense increased on an absolute basis for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to higher legal costs as well as higher personnel costs due to increased workforce headcount.

Depreciation and depletion. Production depletion expense increased on an absolute and per Mcfe basis for the three months ended June 30, 2024 compared to the same period in 2023 due to higher annual depletion rate and increased sales volume.

(Gain) loss on sale/exchange of long-lived assets. During the three months ended June 30, 2024, we recognized a gain on the NEPA Non-Operated Asset Divestiture of approximately $320.0 million. See Note 9 to the Condensed Consolidated Financial Statements.

Impairment and expiration of leases. During the three months ended June 30, 2024 and 2023, we recognized impairment and expiration of leases of $37.7 million and $5.3 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the three months ended June 30, 2024 compared to the same period in 2023 due primarily to increased legal and environmental reserves as well as transaction costs related to the Equitrans Midstream Merger, partly offset by lower transaction costs related to the Tug Hill and XcL Midstream Acquisition.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Six Months Ended June 30, 2024 Compared to Six Months Ended June 30, 2023

			Six Months Ended June 30,
			2024						2023						Change						% Change
			(Thousands, unless otherwise noted)
Operating expenses:
Gathering			$	606,292					$	625,755					$	(19,463)					(3.1)
Transmission			346,821						307,079						39,742						12.9
Processing			135,135						105,312						29,823						28.3
LOE			113,901						64,016						49,885						77.9
Production taxes			90,605						38,962						51,643						132.5
Exploration			2,294						2,155						139						6.5
Selling, general and administrative			140,260						112,057						28,203						25.2
Production depletion			$	938,037					$	772,886					$	165,151					21.4
Other depreciation and depletion			14,695						10,483						4,212						40.2
Total depreciation and depletion			$	952,732					$	783,369					$	169,363					21.6
Per Unit ($/Mcfe):
Gathering			$	0.58					$	0.67					$	(0.09)					(13.4)
Transmission			0.33						0.33						—						—
Processing			0.13						0.11						0.02						18.2
LOE			0.11						0.07						0.04						57.1
Production taxes			0.09						0.04						0.05						125.0
Selling, general and administrative			0.13						0.12						0.01						8.3
Production depletion			0.90						0.83						0.07						8.4

Gathering. Gathering expense decreased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to the lower gathering cost structure that resulted from our acquisition of the remaining minority interest in the NEPA Gathering System during the second quarter of 2024. In addition, gathering expense per Mcfe for the six months ended June 30, 2024 compared to the same period in 2023 benefited from our ownership of the gathering assets acquired in the Tug Hill and XcL Midstream Acquisition during the third quarter of 2023.

Transmission. Transmission expense increased on an absolute basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to additional capacity acquired as well as credits received from the Texas Eastern Transmission Pipeline in 2023.

Processing. Processing expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to increased processing expense from the liquids-rich assets acquired in the Tug Hill and XcL Midstream Acquisition.

LOE. LOE increased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to increased LOE from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

Production taxes. Production taxes increased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to increased West Virginia property tax expense from the assets acquired in the Tug Hill and XcL Midstream Acquisition and higher price as well as increased severance tax expense from increased volumes from the assets acquired in the Tug Hill and XcL Midstream Acquisition.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Selling, general and administrative. Selling, general and administrative expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to higher legal costs as well as higher personnel costs due to increased workforce headcount.

Depreciation and depletion. Production depletion expense increased on an absolute and per Mcfe basis for the six months ended June 30, 2024 compared to the same period in 2023 due to increased sales volume and higher annual depletion rate.

(Gain) loss on sale/exchange of long-lived assets. During the six months ended June 30, 2024, we recognized a gain on the NEPA Non-Operated Asset Divestiture of approximately $320.0 million. See Note 9 to the Condensed Consolidated Financial Statements. During the six months ended June 30, 2023, we recognized a loss on exchange of long-lived assets of $16.3 million related to acreage trade agreements where the carrying value of the acres traded exceeded the fair value of the acres received.

Impairment and expiration of leases. During the six months ended June 30, 2024 and 2023, we recognized impairment and expiration of leases of $46.9 million and $15.9 million, respectively, related to leases that we no longer expect to extend or develop prior to their expiration based on our development plan.

Other operating expenses. Other operating expenses increased for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to transaction costs related to the Equitrans Midstream Merger and increased legal and environmental reserves, partly offset by lower transaction costs related to the Tug Hill and XcL Midstream Acquisition.

Other Income Statement Items

Income from investments. Income from investments decreased for the six months ended June 30, 2024 compared to the same period in 2023 due primarily to lower equity earnings from our equity method investments.

Loss (gain) on debt extinguishment. During the three months ended June 30, 2024 and 2023, we recognized a loss on debt extinguishment of $1.8 million and $5.5 million, respectively, due to our repayment and repurchase of certain of our senior notes at a premium to par value.

During the six months ended June 30, 2024, we recognized a loss on debt extinguishment of $5.3 million due to our prepayment of a portion of the Term Loan Facility (defined in Note 6 to the Condensed Consolidated Financial Statements) as well as our redemption of our 6.125% senior notes at a premium to par value. During the six months ended June 30, 2023, we recognized a gain on debt extinguishment of $1.1 million due to our repayment and repurchase of certain of our senior notes at a discount to par value during the first quarter of 2023, partly offset by the loss recognized during the three months ended June 30, 2023.

Other income. During the six months ended June 30, 2024, we received proceeds from insurance claim recoveries of $19.1 million related to the assets acquired in the Tug Hill and XcL Midstream Acquisition.

Interest expense, net. Interest expense, net increased for both the three and six months ended June 30, 2024 compared to the same periods in 2023 due primarily to lower interest income earned on cash on hand as well as the interest expense on our 5.750% senior notes issued in January 2024 and the interest expense on our borrowings under the Term Loan Facility, partly offset by lower interest expense due to our repayment and repurchase of certain of our senior notes as well as higher capitalized interest from the assets acquired in the Tug Hill and XcL Midstream Acquisition. See Note 6 to the Condensed Consolidated Financial Statements.

Income tax (benefit) expense. See Note 5 to the Condensed Consolidated Financial Statements.

Capital Resources and Liquidity

Although we cannot provide any assurance, we believe cash flows from operating activities and availability under our revolving credit facility should be sufficient to meet our cash requirements inclusive of, but not limited to, normal operating needs, debt service obligations, planned capital expenditures and commitments for at least the next twelve months and, based on current expectations, for the long term.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Planned Capital Expenditures and Sales Volume. Following the completion of the Equitrans Midstream Merger, we revised our estimated total capital expenditures for the third quarter of 2024 to $620 million to $720 million and fourth quarter of 2024 to $580 million to $680 million. We expect to fund our capital expenditures with cash generated from operations and, if required, borrowings under our revolving credit facility. Because we are the operator of a high percentage of our developed acreage, the amount and timing of certain of our capital expenditures is largely discretionary. We could choose to defer a portion of our planned 2024 capital expenditures depending on a variety of factors, including prevailing and anticipated prices for natural gas, NGLs and oil; the availability of necessary equipment, infrastructure and capital; the receipt and timing of required regulatory permits and approvals; and drilling, completion and acquisition costs. We expect our sales volume, including expected curtailments, to be 510 Bcfe to 560 Bcfe for the third quarter of 2024 and 515 Bcfe to 565 Bcfe for the fourth quarter of 2024.

Operating Activities. Net cash provided by operating activities was $1,478 million for the six months ended June 30, 2024 compared to $2,100 million for the same period in 2023. The decrease was due primarily to lower cash operating revenues, unfavorable timing of working capital payments and higher operating expenses, partly offset by higher net cash settlements received on derivatives and lower net premiums paid on derivatives.

Our cash flows from operating activities are affected by movements in the market price for commodities. We are unable to predict such movements outside of the current market view as reflected in forward strip pricing. For a discussion of potential commodity market risks, refer to "Risk Factors – Natural gas, NGLs and oil price volatility, or a prolonged period of low natural gas, NGLs and oil prices, may have an adverse effect on our revenue, profitability, future rate of growth, liquidity and financial position" in our Annual Report on Form 10-K for the year ended December 31, 2023.

Investing Activities. Net cash used in investing activities was $879 million for the six months ended June 30, 2024 compared to $984 million for the same period in 2023. The decrease was attributable primarily to proceeds received from the NEPA Non-Operated Asset Divestiture, partly offset by cash paid for the NEPA Gathering System Acquisition and increased capital expenditures.

The following table summarizes our capital expenditures.

			Three Months Ended June 30,												Six Months Ended June 30,
			2024						2023						2024						2023
			(Millions)
Reserve development (a)			$	460					$	399					$	912					$	792
Land and lease (b)			41						24						68						60
Other production infrastructure			19						18						41						32
Midstream			16						3						29						4
Capitalized overhead			17						15						34						29
Capitalized interest			16						9						33						19
Other			7						5						8						6
Total capital expenditures			576						473						1,125						942
(Deduct) add: Non-cash items (c)			(17)						14						(32)						40
Total cash capital expenditures			$	559					$	487					$	1,093					$	982

(a)Includes capital expenditures for water infrastructure of $14.6 million and $7.7 million for the three months ended June 30, 2024 and 2023, respectively, and $29.8 million and $18.7 million for the six months ended June 30, 2024 and 2023, respectively.

(b)Capital expenditures attributable to noncontrolling interests were $3.1 million and $8.5 million for the three and six months ended June 30, 2023, respectively. There were no capital expenditures attributable to noncontrolling interests for the three and six months ended June 30, 2024.

(c)Represents the net impact of non-cash capital expenditures, including the effect of timing of receivables from working interest partners, accrued capital expenditures and capitalized share-based compensation costs. The impact of accrued capital expenditures includes the current period estimate, net of the reversal of the prior period accrual.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Financing Activities. Net cash used in financing activities was $649 million for the six months ended June 30, 2024 compared to $1,359 million for the same period in 2023. For the six months ended June 30, 2024, the primary uses of financing cash flows were our prepayment of a portion of the Term Loan Facility, redemption of our 6.125% senior notes and payment of dividends, and the primary sources of financing cash flows were proceeds from the issuance of our 5.750% senior notes and proceeds from the net settlement of the Capped Call Transactions (defined in Note 6 to the Condensed Consolidated Financial Statements). For the six months ended June 30, 2023, the primary uses of financing cash flows were our repayment and retirement of debt, repurchase and retirement of EQT Corporation common stock and payment of dividends.

See Note 6 to the Condensed Consolidated Financial Statements for further discussion of our debt and borrowings under our revolving credit facility and the Term Loan Facility, including financing activities entered into in connection with the completion of the Equitrans Midstream Merger. In connection with the completion of the Equitrans Midstream Merger, we acquired Equitrans Midstream's controlling interest in EQM Midstream Partners, LP (EQM), which will be consolidated into our financial statements in the third quarter of 2024. As of June 30, 2024, EQM had outstanding senior notes in an aggregate principal amount of approximately $7 billion.

On July 16, 2024, our Board of Directors declared a quarterly cash dividend of $0.1575 per share of EQT Corporation common stock, payable on September 1, 2024, to shareholders of record at the close of business on August 7, 2024.

Depending on our actual and anticipated sources and uses of liquidity, prevailing market conditions and other factors, we may from time to time seek to redeem or repurchase our outstanding debt or equity securities through tender offers or other cash purchases in the open market or privately negotiated transactions. The amounts involved in any such transactions may be material. See Note 6 to the Condensed Consolidated Financial Statements for discussion of redemptions and repurchases of debt.

Material Cash Requirement. On June 25, 2024, we delivered to Equitrans Midstream a written election exercising our right under the Merger Agreement to cause Equitrans Midstream to purchase and redeem, prior to the completion of the Equitrans Midstream Merger, all of the issued and outstanding Equitrans Midstream Preferred Stock (defined in Note 10 to the Condensed Consolidated Financial Statements). On July 22, 2024, prior to the closing of the Equitrans Midstream Merger, using borrowings under our revolving credit facility, we paid $685.3 million to effect such purchase and redemption..

Security Ratings and Financing Triggers

The table below reflects the credit ratings and rating outlooks assigned to our debt instruments as of June 30, 2024. Our credit ratings and rating outlooks are subject to revision or withdrawal at any time by the assigning rating agency, and each rating should be evaluated independently from any other rating. We cannot ensure that a rating will remain in effect for any given period of time or that a rating will not be lowered or withdrawn by a rating agency if, in the rating agency's judgment, circumstances so warrant. See Note 3 to the Condensed Consolidated Financial Statements for a description of what is deemed investment grade.

Rating agency						Senior notes						Outlook
Moody's Investor Service (Moody's)						Baa3						Negative
Standard and Poor's Ratings Service (S&P)						BBB–						Negative
Fitch Ratings Service (Fitch)						BBB–						Stable

Changes in credit ratings may affect our access to the capital markets, the cost of short-term debt through interest rates and fees under our revolving credit facility, the interest rate on the Term Loan Facility and senior notes with adjustable rates, the rates available on new long-term debt, our pool of investors and funding sources, the borrowing costs and margin deposit requirements on our over the counter (OTC) derivative instruments and credit assurance requirements, including collateral, in support of our midstream service contracts, joint venture arrangements or construction contracts. Margin deposits on our OTC derivative instruments are also subject to factors other than credit rating, such as natural gas prices and credit thresholds set forth in the agreements between us and our hedging counterparties.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Our debt agreements and other financial obligations contain various provisions that, if not complied with, could result in default or event of default under our revolving credit facility and the Term Loan Facility, mandatory partial or full repayment of amounts outstanding, reduced loan capacity or other similar actions. The most significant covenants and events of default under our debt agreements relate to maintenance of a debt-to-total capitalization ratio, limitations on transactions with affiliates, insolvency events, nonpayment of scheduled principal or interest payments, acceleration of other financial obligations and change of control provisions. Our revolving credit facility and the Term Loan Facility contain financial covenants that require us to have a total debt to total capitalization ratio no greater than 65%. As of June 30, 2024, we were in compliance with all debt provisions and covenants under our debt agreements.

See Note 6 to the Condensed Consolidated Financial Statements for a discussion of borrowings under our revolving credit facility and the Term Loan Facility.

Commodity Risk Management

The substantial majority of our commodity risk management program is related to hedging sales of our produced natural gas. The overall objective of our hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices. The derivative commodity instruments that we use are primarily swap, collar and option agreements. The following table summarizes the approximate volume and prices of our NYMEX hedge positions as of July 19, 2024. The difference between the fixed price and NYMEX price is included in average differential presented in our price reconciliation in "Average Realized Price Reconciliation." The fixed price natural gas sales agreements can be physically or financially settled.

			Q3 2024 (a)						Q4 2024						Q1 2025						Q2 2025						Q3 2025						Q4 2025
Hedged Volume (MMDth)			291						362						332						336						71						33
Hedged Volume (MMDth/d)			3.2						3.9						3.7						3.7						0.8						0.4
Swaps – Short
Volume (MMDth)			246						289						144						290						71						33
Avg. Price ($/Dth)			$	3.14					$	3.21					$	3.42					$	3.11					$	3.34					$	3.35
Calls – Long
Volume (MMDth)			13						13						—						—						—						—
Avg. Strike ($/Dth)			$	3.20					$	3.20					$	—					$	—					$	—					$	—
Calls – Short
Volume (MMDth)			62						90						188						46						—						—
Avg. Strike ($/Dth)			$	4.22					$	4.25					$	4.19					$	3.48					$	—					$	—
Puts – Long
Volume (MMDth)			45						73						188						46						—						—
Avg. Strike ($/Dth)			$	4.05					$	3.54					$	3.20					$	2.83					$	—					$	—
Option Premiums
Cash Settlement of Deferred Premiums (millions)			$	(4)					$	—					$	—					$	—					$	—					$	—

(a)July 1 through September 30.

We have also entered into derivative instruments to hedge basis. We may use other contractual agreements to implement our commodity hedging strategy from time to time.

See "Quantitative and Qualitative Disclosures About Market Risk" and Note 3 to the Condensed Consolidated Financial Statements for further discussion of our hedging program.

EQT CORPORATION AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

Commitments and Contingencies

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts claimed may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We evaluate our legal proceedings, including litigation and regulatory and governmental investigations and inquiries, on a regular basis and accrue a liability for such matters when we believe that a loss is probable and the amount of the loss can be reasonably estimated. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event we determine that (i) a loss is probable but the amount of the loss cannot be reasonably estimated, or (ii) a loss is less likely than probable but is reasonably possible, then we are required to disclose the matter in our Annual Report on Form 10-K with any update thereto in this Quarterly Report on Form 10-Q, as applicable, although we are not required to accrue such loss.

When able, we determine an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any related accrued liability or where there is no accrued liability, for legal proceedings. In instances where such estimates can be made, any such estimates are based on our analysis of currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained.

See Note 11 to the Condensed Consolidated Financial Statements herein and Note 11 to the Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2023 for discussions of our commitments and contingencies, including certain pending legal and regulatory proceedings and other contingent matters.

Additionally, in the normal course of business, we are subject to various other pending and threatened legal proceedings in which claims for monetary damages or other relief are asserted. We do not anticipate, at the present time, that the ultimate aggregate liability, if any, arising out of such other legal proceedings will have a material adverse effect on our financial position, results of operations or liquidity.

Critical Accounting Policies and Estimates

Our critical accounting policies, including a discussion regarding the estimation uncertainty and the impact that our critical accounting estimates have had, or are reasonably likely to have, on our financial condition or results of operations, are described in the "Management's Discussion and Analysis of Financial Condition and Results of Operations" section of our Annual Report on Form 10-K for the year ended December 31, 2023. The application of our critical accounting policies may require us to make judgments and estimates about the amounts reflected in the Condensed Consolidated Financial Statements. We use historical experience and all available information to make these estimates and judgments. Different amounts could be reported using different assumptions and estimates.