Comstock Resources 10Q 2023 Q1 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2023


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File No. 001-03262

COMSTOCK RESOURCES, INC.

(Exact name of registrant as specified in its charter)


Nevada			94-1667468
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification Number)

5300 Town and Country Blvd., Suite 500, Frisco, Texas 75034

(Address of principal executive offices)

Telephone No.: (972) 668-8800

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.50 (per share)	CRK	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Yes x No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer", "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer x

Emerging growth company ☐

Accelerated filer ☐

Non-accelerated ☐

Smaller reporting company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No x

The number of shares outstanding of the registrant's common stock, par value $0.50, as of May 3, 2023 was 277,510,165.

COMSTOCK RESOURCES, INC.

QUARTERLY REPORT

For the Quarter Ended March 31, 2023

INDEX

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS


	As of
	March 31, 2023		December 31, 2022
	(Unaudited)
	(In thousands)
ASSETS
Cash and cash equivalents	$	33,677	$	54,652
Accounts receivable:
Oil and gas sales and gas services	177,751		415,079
Joint interest operations	65,792		76,521
From affiliates	10,592		18,527
Derivative financial instruments	75,490		23,884

Other current assets	59,522		56,324
Total current assets	422,824		644,987
Property and equipment:
Oil and natural gas properties, successful efforts method:
Proved	6,183,336		5,843,409
Unproved	324,773		298,230
Other	30,801		26,475
Accumulated depreciation, depletion and amortization	(1,679,211)		(1,545,459)
Net property and equipment	4,859,699		4,622,655
Goodwill	335,897		335,897


Operating lease right-of-use assets	82,461		90,716

	$	5,700,881	$	5,694,255

LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable	$	443,501	$	530,195
Accrued costs	145,779		183,111
Operating leases	39,031		38,411
Derivative financial instruments	—		4,420
Total current liabilities	628,311		756,137
Long-term debt	2,154,424		2,152,571
Deferred income taxes	464,914		425,734

Long-term operating leases	43,504		52,385
Reserve for future abandonment costs	29,553		29,114

Total liabilities	3,320,706		3,415,941
Commitments and contingencies


Stockholders' equity:
Common stock—$0.50 par, 400,000,000 shares authorized, 277,510,165 and 277,517,087 shares issued and outstanding at March 31, 2023 and December 31, 2022, respectively	138,755		138,759
Additional paid-in capital	1,255,467		1,253,417
Accumulated earnings	985,953		886,138
Total stockholders' equity	2,380,175		2,278,314
	$	5,700,881	$	5,694,255

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three Months Ended March 31,
	2023		2022
	(In thousands, except per share amounts)
Revenues:
Natural gas sales	$	378,032	$	522,957
Oil sales	1,942		1,884
Total natural gas and oil sales	379,974		524,841
Gas services	109,604		—
Total revenues	489,578		524,841
Operating expenses:
Production and ad valorem taxes	14,906		13,820
Gathering and transportation	45,574		32,093
Lease operating	34,830		26,186
Exploration	1,775		1,021
Depreciation, depletion and amortization	133,983		106,728
Gas services	101,295		—
General and administrative	12,368		8,223
Gain on sale of assets	(773)		(2)
Total operating expenses	343,958		188,069

Operating income	145,620		336,772
Other income (expenses):
Gain (loss) from derivative financial instruments	66,409		(437,493)
Other income	460		4,166

Interest expense	(38,270)		(46,491)

Total other income (expenses)	28,599		(479,818)
Income (loss) before income taxes	174,219		(143,046)
(Provision for) benefit from income taxes	(39,716)		31,622
Net income (loss)	134,503		(111,424)
Preferred stock dividends	—		(4,315)
Net income (loss) available to common stockholders	$	134,503	$	(115,739)

Net income (loss) per share:
Basic	$	0.49	$	(0.50)
Diluted	$	0.49	$	(0.50)
Weighted average shares outstanding:
Basic	276,551		231,976
Diluted	276,551		231,976
Dividends per share	$	0.125	$	—

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(Unaudited)


	Common Shares	Common Stock- Par Value		Additional Paid-in Capital		Accumulated Earnings (Deficit)		Total
	(In thousands)

Balance at January 1, 2022	232,925	$	116,462	$	1,100,359	$	(204,042)	$	1,012,779
Stock-based compensation	(5)	(2)		1,479		—		1,477


Net loss	—	—		—		(111,424)		(111,424)
Payment of preferred stock dividends	—	—		—		(4,315)		(4,315)
Balance at March 31, 2022	232,920	$	116,460	$	1,101,838	$	(319,781)	$	898,517













Balance at January 1, 2023	277,517	$	138,759	$	1,253,417	$	886,138	$	2,278,314
Stock-based compensation	(7)	(4)		2,050		—		2,046


Net income	—	—		—		134,503		134,503
Payment of common stock dividends	—	—		—		(34,688)		(34,688)
Balance at March 31, 2023	277,510	$	138,755	$	1,255,467	$	985,953	$	2,380,175

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Three Months Ended March 31,
	2023		2022
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	134,503	$	(111,424)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Deferred income taxes	39,180		(24,788)

Gain on sale of assets	(773)		(2)
Depreciation, depletion and amortization	133,983		106,728
(Gain) loss on derivative financial instruments	(66,409)		437,493
Cash settlements of derivative financial instruments	10,383		(117,186)
Amortization of debt discount and issuance costs	1,997		4,225
Stock-based compensation	2,046		1,495

Decrease in accounts receivable	255,992		28,125
(Increase) decrease in other current assets	(1,514)		2,985
Decrease in accounts payable and accrued expenses	(123,024)		(42,033)
Net cash provided by operating activities	386,364		285,618
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures and acquisitions	(370,953)		(213,277)
Prepaid drilling costs	(1,684)		(1,579)
Proceeds from sales of assets	130		45
Net cash used for investing activities	(372,507)		(214,811)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on bank credit facility	—		95,000
Repayments of bank credit facility	—		(180,000)




Preferred stock dividends paid	—		(4,315)
Common stock dividends paid	(34,688)		—
Debt and stock issuance costs	(144)		—
Income tax withholdings on equity awards	—		(18)
Net cash used for financing activities	(34,832)		(89,333)
Net decrease in cash and cash equivalents	(20,975)		(18,526)
Cash and cash equivalents, beginning of period	54,652		30,663
Cash and cash equivalents, end of period	$	33,677	$	12,137

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

March 31, 2023

(Unaudited)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES –

Basis of Presentation

These unaudited consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly-owned subsidiaries (collectively, "Comstock" or the "Company"). In management's opinion, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly the financial position of Comstock as of March 31, 2023, and the related results of operations and cash flows for the periods being presented. Net income and comprehensive income are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

The accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to those rules and regulations, although Comstock believes that the disclosures made are adequate to make the information presented not misleading. These unaudited consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in Comstock's Annual Report on Form 10-K for the year ended December 31, 2022. The results of operations for the period through March 31, 2023 are not necessarily an indication of the results expected for the full year.

Other Current Assets

Other current assets at March 31, 2023 and December 31, 2022 consisted of the following:


	As of
	March 31, 2023		December 31, 2022
	(In thousands)
Pipe and well equipment inventory	$	40,170	$	34,819
Production tax refunds receivable	15,236		11,156
Prepaid expenses	2,543		2,455
Prepaid drilling costs	598		4,265
Accrued proceeds from sale of oil and gas properties	975		3,118
Other	—		511
	$	59,522	$	56,324

Property and Equipment

The Company follows the successful efforts method of accounting for its oil and natural gas properties. Costs incurred to acquire oil and gas leases and to drill and complete developmental wells are capitalized.

Exploratory well costs are initially capitalized as proved property in the consolidated balance sheets but charged to exploration expense if and when the well is determined not to have found commercial proved oil and gas reserves. The changes in capitalized exploratory well costs are as follows:


	Three Months Ended March 31,		Three Months Ended March 31,
	2023		2022
	(In thousands)
Beginning capitalized exploratory well costs	$	867	$	6,966
Additions to exploratory well costs pending the determination of proved reserves	29,690		11,557



Ending capitalized exploratory well costs	$	30,557	$	18,523

As of March 31, 2023 and December 31, 2022, the Company had no exploratory wells for which costs have been capitalized for a period greater than one year.

The Company assesses the need for an impairment of the capitalized costs for its proved oil and gas properties on a property basis. No impairments were recognized to adjust the carrying value of the Company's proved oil and gas properties during any of the periods presented. Unproved oil and gas properties are also periodically assessed and any impairment in value is charged to expense. The costs related to unproved properties are transferred to proved oil and gas properties and amortized on an equivalent unit-of-production basis when they are reflected in proved oil and natural gas reserves.

The Company determines the fair values of its oil and gas properties using a discounted cash flow model and proved and risk-adjusted probable oil and natural gas reserves. Undrilled acreage can also be valued based on sales transactions in comparable areas. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for oil and natural gas prices, production costs, capital expenditures, and future production as well as estimated proved oil and gas reserves and risk-adjusted probable oil and natural gas reserves. Management's oil and natural gas price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value.

It is reasonably possible that the Company's estimates of undiscounted future net cash flows attributable to its oil and gas properties may change in the future. The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable oil and gas reserves, results of future drilling activities, future prices for oil and natural gas, and increases or decreases in production and capital costs. As a result of these changes, there may be future impairments in the carrying values of these or other properties.

Goodwill

The Company had goodwill of $335.9 million as of March 31, 2023 that was recorded in 2018. The Company is not required to amortize goodwill as a charge to earnings; however, the Company is required to conduct an annual review of goodwill for impairment. The Company performs an annual assessment of goodwill on October 1 of each year and performs interim assessments if indicators of impairment are present. If the carrying value of goodwill exceeds the fair value, an impairment charge would be recorded for the difference between fair value and carrying value.

Leases

The Company has right-of-use lease assets of $82.5 million related to its corporate office, certain office equipment, vehicles and a hydraulic fracturing fleet used to complete natural gas wells with corresponding short-term and long-term liabilities. The value of the lease assets and liabilities are determined based upon discounted future minimum cash flows contained within each of the respective contracts. The Company determines if contracts contain a lease at inception of the contract. To the extent that contract terms representing a lease are identified, leases are identified as being either an operating lease or a finance-type lease. Comstock currently has no finance-type leases. Right-of-use lease assets representing the Company's right to use an underlying asset for the lease term and the related lease liabilities represent our obligation to make lease payments under the terms of the contracts. Short-term leases that have an initial term of one year or less are not capitalized; however, amounts paid for those leases are included as part of its lease cost disclosures. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Leases for the right to explore for and develop oil and natural gas reserves and the related rights to use the land associated with those leases are reflected as oil and gas properties.

Comstock contracts for a variety of equipment used in its oil and natural gas exploration and development activities. Contract terms for this equipment vary broadly, including the contract duration, pricing, scope of services included along with the equipment, cancellation terms, and rights of substitution, among others. The Company's drilling and completion operations routinely change due to changes in commodity prices, demand for oil and natural gas, and the overall operating and economic environment. Accordingly, Comstock manages the terms of its contracts for drilling rigs and completion equipment so as to allow for maximum flexibility in responding to these changing conditions. The Company is currently utilizing a natural gas powered hydraulic fracturing fleet, which has been leased with a three year term. The Company's other hydraulic fracturing fleet contracts are on terms less than one year and include rights of substitution. The Company's drilling rig contracts are presently either for periods of less than one year, or they are on terms that provide for cancellation with 45 days advance notice without a specified expiration date. The Company has elected not to recognize right-of-use lease assets for contracts less than one year. The costs associated with drilling and completion operations are accounted for under the successful efforts method, which generally require that these costs be capitalized as part of our proved oil and natural gas properties on our balance sheet unless they are incurred on exploration wells that are unsuccessful, in which case they are charged to exploration expense.

Lease costs recognized during the three months ended March 31, 2023 and 2022 were as follows:


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Operating lease cost included in general and administrative expense	$	445	$	435
Operating lease cost included in lease operating expense	508		270
Operating lease cost included in oil and natural gas properties	9,450		—
Variable lease cost (completion costs included in oil and natural gas properties)	1,761		—
Short-term lease cost (drilling rig costs included in oil and natural gas properties)	29,392		11,035
	$	41,556	$	11,740

Cash payments for operating leases associated with right-of-use assets included in cash provided by operating activities were $1.0 million and $0.7 million for the three months ended March 31, 2023 and 2022, respectively. Cash payments for operating leases associated with right-of-use assets included in cash used for investing activities were $40.6 million and $11.0 million for the three months ended March 31, 2023 and 2022, respectively.

As of March 31, 2023 and December 31, 2022, the operating leases had a weighted-average term of 2.0 years and 2.2 years, respectively, and the weighted-average discount rate used to determine the present value of future operating lease payments was 3.6% and 3.5%, respectively. As of March 31, 2023, the Company also had expected future payments for contracted drilling services of $148.7 million.

As of March 31, 2023, expected future payments related to contracts that contain operating leases were as follows:


	(In thousands)
April 1 to December 31, 2023	$	30,753
2024	41,238
2025	13,650
2026	158
2027	17

Total lease payments	85,816
Imputed interest	(3,281)
Total lease liability	$	82,535

Accrued Costs

Accrued costs at March 31, 2023 and December 31, 2022 consisted of the following:


	As of
	March 31, 2023		December 31, 2022
	(In thousands)
Accrued drilling costs	$	53,429	$	54,438
Accrued income and other taxes	36,776		31,256
Accrued transportation costs	28,135		28,357
Accrued interest payable	19,697		54,867
Accrued employee compensation	5,023		11,308

Accrued lease operating expenses	2,324		2,412
Other	395		473
	$	145,779	$	183,111

Reserve for Future Abandonment Costs

Comstock's asset retirement obligations relate to future plugging and abandonment expenses on its oil and gas properties and disposal of other facilities. The following table summarizes the changes in Comstock's total estimated liability for such obligations during the periods presented:


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Reserve for future abandonment costs at beginning of period	$	29,114	$	25,673
New wells placed on production	30		381


Accretion expense	409		362
Reserve for future abandonment costs at end of period	$	29,553	$	26,416

Derivative Financial Instruments and Hedging Activities

All of the Company's derivative financial instruments are used for risk management purposes and, by policy, none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums. The Company classifies the fair value amounts of derivative financial instruments as net current or noncurrent assets or liabilities, whichever the case may be, by commodity contract. None of the Company's derivative contracts were designated as cash flow hedges. All of Comstock's natural gas derivative financial instruments are tied to the Henry Hub-NYMEX price index.

The Company had the following oil and natural gas price derivative financial instruments at March 31, 2023:

Future Production Period

Nine Months Ending December 31, 2023

Natural Gas Collar Contracts:

Volume (MMBtu)

107,425,000

Average Price per MMBtu:

Average Ceiling

$10.22

Average Floor

$3.00

The classification of derivative financial instruments of assets or liabilities, consists of the following:


		As of
Type	Consolidated Balance Sheet Location	March 31, 2023		December 31, 2022
		(In thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	75,490	$	23,884

		$	75,490	$	23,884





Liability Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	—	$	4,420


		$	—	$	4,420

The Company recognized cash settlements and changes in the fair value of its derivative financial instruments as a single component of other income (expenses). Gains and losses related to cash settlements and changes in the fair value recognized on the Company's derivative contracts recognized in the consolidated statement of operations were as follows:


Gain (Loss) on Derivatives Recognized in Earnings	Three Months Ended March 31,
	2023		2022
	(In thousands)
Natural gas price derivatives	$	66,409	$	(437,493)


	$	66,409	$	(437,493)

Stock-Based Compensation

Comstock accounts for employee stock-based compensation under the fair value method. Compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period and included in general and administrative expenses for awards of restricted stock and performance stock units ("PSUs") to the Company's employees and directors. The Company recognized $2.0 million and $1.5 million of stock-based compensation expense within general and administrative expenses related to awards of restricted stock and PSUs to its employees and directors during the three months ended March 31, 2023 and 2022, respectively.

As of March 31, 2023, Comstock had 959,136 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $13.30 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $8.8 million as of March 31, 2023 is expected to be recognized over a period of 2.1 years.

As of March 31, 2023, Comstock had 552,126 PSUs outstanding with a weighted average grant date fair value of $14.76 per unit. The number of shares of common stock to be issued related to the PSUs is based on the Company's stock price performance as compared to its peers which could result in the issuance of anywhere from zero to 1,104,252 shares of common stock. Total unrecognized compensation cost related to these grants of $4.7 million as of March 31, 2023 is expected to be recognized over a period of 2.0 years.

Revenue Recognition

Comstock produces natural gas and oil and reports revenues separately for each of these two primary products in its statements of operations. Revenues are recognized upon the transfer of produced volumes to the Company's customers, who take control of the volumes and receive all the benefits of ownership upon delivery at designated sales points.

Gas services revenues represent sales of natural gas purchased for resale and fees received for gathering and treating services provided to unaffiliated third parties and certain natural gas wells operated by the Company. Revenues are recognized upon completion of the gathering and treating of contracted natural gas volumes and delivery of purchased natural gas volumes to the Company's customers. Profits and losses earned in the gathering and treating of natural gas produced by the Company's natural gas wells are eliminated in consolidation. Revenues and expenses associated with natural gas purchased for resale are presented on a gross basis in the Company's consolidated statements of operations as the Company acts as the principal in the transaction by assuming the risks and rewards from ownership of the natural gas volumes purchased and the responsibility to deliver the natural gas volumes to their sales point.

All natural gas and oil and gas services revenues are subject to contracts that have commercial substance, contain specific pricing terms, and define the enforceable rights and obligations of both parties. These contracts typically provide for cash settlement within 25 days following each production month and are cancellable upon 30 days' notice by either party for oil and vary for natural gas based upon the terms set out in the confirmations between both parties. Prices for sales of natural gas and oil are generally based upon terms that are common in the oil and gas industry, including index or spot prices, location and quality differentials, as well as market supply and demand conditions. As a result, prices for natural gas and oil routinely fluctuate based on changes in these factors. Prices for gathering and treating services are generally fixed in nature but can vary due to the quality of the gas being treated. Each unit of production (barrel of crude oil and thousand cubic feet of natural gas) represents a separate performance obligation under the Company's contracts since each unit has economic benefit on its own and each is priced separately according to the terms of the contracts.

Comstock has elected to exclude all taxes from the measurement of transaction prices, and its revenues are reported net of royalties and exclude revenue interests owned by others because the Company acts as an agent when selling crude oil and natural gas, on behalf of royalty owners and working interest owners. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. Gas services revenue is recorded in the month the services are performed or purchased gas is sold based on an estimate of natural gas volumes and contract prices. The Company recognizes any differences between estimates and actual amounts received in the month when payment is received. Historically, differences between estimated revenues and actual revenue received have not been significant. The amount of natural gas or oil sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at March 31, 2023 or December 31, 2022.

The Company recognized accounts receivable of $177.8 million and $415.1 million as of March 31, 2023 and December 31, 2022, respectively, from purchasers for contracts where performance obligations have been satisfied and an unconditional right to consideration exists.

Credit Losses

Substantially all of the Company's accounts receivable are due from either purchasers of natural gas and oil or participants in natural gas and oil wells for which the Company serves as the operator. Generally, operators of natural gas and oil wells have the right to offset future revenues against unpaid charges related to operated wells. Natural gas and oil sales are generally unsecured. Comstock assesses the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been recorded for the three months ended March 31, 2023 and 2022.

Income Taxes

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates.

In recording deferred income tax assets, the Company considers whether it is more likely than not that its deferred income tax assets will be realized in the future. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized. As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods. The Company will continue to assess the valuation allowances against deferred tax assets considering all available information obtained in future periods.

The following is an analysis of the consolidated income tax provision (benefit):


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Current - Federal	$	—	$	(3,961)
Current - State	536		(2,460)
Deferred - Federal	36,765		(13,424)
Deferred - State	2,415		(11,777)
	$	39,716	$	(31,622)

The difference between the federal statutory rate of 21% and the effective tax rate is due to the following:


	Three Months Ended March 31,
	2023		2022
Tax at statutory rate	21.0	%	21.0	%
Tax effect of:
Valuation allowance on deferred tax assets	0.5		(3.6)
State income taxes, net of federal benefit	1.0		4.6
Nondeductible stock-based compensation	0.4		0.1


Effective tax rate	22.9	%	22.1	%

The Company's federal income tax returns for the years subsequent to December 31, 2018 remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2019. The Company is currently under examination with the state of Louisiana and believes that its significant filing positions are highly certain and that all of its other significant income tax filing positions and deductions would be sustained under audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions.

Fair Value Measurements

The Company holds or has held certain financial assets and liabilities that are required to be measured at fair value. These include cash and cash equivalents held in bank accounts and derivative financial instruments. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 — Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Level 2 — Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 — Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

Fair Values – Reported

The following presents the carrying amounts and the fair values of the Company's financial instruments as of March 31, 2023 and December 31, 2022:


	As of
	March 31, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
Assets:	(In thousands)
Commodity-based derivatives (1)	$	75,490	$	75,490	$	23,884	$	23,884
Liabilities:
Commodity-based derivatives (1)	$	—	$	—	$	4,420	$	4,420



6.75% senior notes due 2029 (2)	$	1,229,639	$	1,101,492	$	1,229,836	$	1,129,029
5.875% senior notes due 2030 (2)	$	965,000	$	822,663	$	965,000	$	846,788

_____________________________

(1)The Company's commodity-based derivatives are classified as Level 2 and measured at fair value using third party pricing services and other active markets or broker quotes that are readily available in the public markets.

(2)The fair value of the Company's fixed rate debt was based on quoted prices as of March 31, 2023 and December 31, 2022, respectively, a Level 1 measurement.

Earnings Per Share

Unvested restricted stock containing non-forfeitable rights to dividends are included in common stock outstanding and are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. At March 31, 2023 and December 31, 2022, 959,136 and 966,058 shares of restricted stock, respectively, are included in common stock outstanding as such shares have a non-forfeitable right to participate in any dividends that might be declared and have the right to vote on matters submitted to the Company's stockholders.

Weighted average shares of unvested restricted stock outstanding were as follows:


	Three Months Ended March 31,
	2023	2022
	(In thousands)
Unvested restricted stock	960	947

PSUs represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the performance period. The treasury stock method is used to measure the dilutive effect of PSUs.

Weighted average unearned PSUs outstanding were as follows:


	Three Months Ended March 31,
	2023	2022
	(In thousands, except per unit amounts)
Weighted average PSUs	548	1,050
Weighted average grant date fair value per unit	$14.76	$8.11

Basic and diluted income (loss) per share for the three months ended March 31, 2023 and 2022 were determined as follows:


	Three Months Ended March 31,
	2023					2022
	Income		Shares	Per Share		Loss		Shares	Per Share
	(In thousands, except per share amounts)
Net income (loss) attributable to common stock	$	134,503				$	(115,739)
Income allocable to unvested restricted shares	(345)					—
Basic income (loss) attributable to common stock	134,158		276,551	$	0.49	(115,739)		231,976	$	(0.50)




Diluted income (loss) attributable to common stock	$	134,158	276,551	$	0.49	$	(115,739)	231,976	$	(0.50)

None of the Company's participating securities participate in losses and as such are excluded from the computation of basic earnings per share during periods of net losses.

Supplementary Information with Respect to the Consolidated Statements of Cash Flows

Cash payments made for interest and income taxes and other non-cash investing activities for the three months ended March 31, 2023 and 2022, respectively, were as follows:


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Cash payments for:
Interest payments	$	71,443	$	75,928
Income tax payments	$	184	$	—
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	(1,009)	$	14,499
Liabilities assumed in exchange for right-of-use lease assets	$	1,417	$	1,089

(2) LONG-TERM DEBT

At March 31, 2023, long-term debt was comprised of the following:


	(In thousands)
6.75% Senior Notes due 2029:
Principal	$	1,223,880
Premium, net of amortization	5,759
5.875% Senior Notes due 2030:
Principal	965,000
Bank Credit Facility:
Principal	—
Debt issuance costs, net of amortization	(40,215)
	$	2,154,424

As of March 31, 2023, the Company had no borrowings outstanding under the bank credit facility. Aggregate commitments under the bank credit facility are $1.5 billion, which matures on November 15, 2027. Borrowings under the bank credit facility are subject to a borrowing base, which is currently set at $2.0 billion. The borrowing base is re-determined on a semi-annual basis and upon the occurrence of certain other events. Borrowings under the bank credit facility are secured by substantially all of the assets of the Company and its subsidiaries and bear interest at the Company's option, at either SOFR plus 1.75% to 2.75% or an alternate base rate plus 0.75% to 1.75%, in each case depending on the utilization of the borrowing base. The Company also pays a commitment fee of 0.375% to 0.5% on the unused portion of the borrowing base. The bank credit facility places certain restrictions upon the Company's and its subsidiaries' ability to, among other things, incur additional indebtedness, pay cash dividends, repurchase common stock, make certain loans, investments and divestitures and redeem the

senior notes. The only financial covenants are the maintenance of a leverage ratio of less than 3.5 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0. The Company was in compliance with the covenants as of March 31, 2023.

(3) CONVERTIBLE PREFERRED STOCK

On November 30, 2022, all of the outstanding shares of the Series B Redeemable Convertible Preferred Stock were converted into 43,750,000 shares of common stock.

(4) COMMITMENTS AND CONTINGENCIES

In July 2022, the Company entered into a hydraulic fracturing services agreement for exclusive use of a natural gas powered hydraulic fracturing fleet. The term of the agreement is three years and the minimum commitment under this agreement is $19.2 million per year. The Company expects to take delivery of the fleet in the second quarter of 2023.

In December 2022, the Company entered into agreements for three new drilling rigs with a three year term and a minimum annual commitment of $12.2 million per drilling rig. Comstock expects to take delivery of two of the rigs in the second half of 2023 and the third rig in early 2024.

From time to time, the Company is involved in certain litigation that arises in the normal course of its operations. The Company records a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company does not believe the resolution of these matters will have a material effect on the Company's financial position, results of operations or cash flows and no material amounts are accrued relative to these matters at March 31, 2023 or 2022.

(5) RELATED PARTY TRANSACTIONS

Comstock operates oil and gas properties held by partnerships owned by its majority stockholder. The Company charges the partnerships for the costs incurred to drill, complete and produce wells, as well as drilling and operating overhead fees. Comstock also provides natural gas marketing services to the partnerships, including evaluating potential markets and providing hedging services, in return for a fee equal to $0.02 per Mcf for natural gas marketed. The Company received $224 thousand and $194 thousand for the three months ended March 31, 2023 and 2022, respectively, for drilling, operating and marketing services provided to the partnerships. The fees received for the services are reflected as a reduction of general and administrative expenses in the accompanying consolidated statements of operations.

In connection with the operation of the wells, the Company had a $10.6 million and $18.5 million receivable from the partnerships at March 31, 2023 and December 31, 2022, respectively.

(6) SUBSEQUENT EVENT

On May 1, 2023, the board of directors of the Company authorized a dividend of $0.125 per share to be paid to common stockholders of record on June 1, 2023.

ITEM 2: MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This report contains forward-looking statements that involve risks and uncertainties that are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Actual results may differ materially from those anticipated in our forward-looking statements due to many factors. The following discussion should be read in conjunction with the consolidated financial statements and notes thereto included in this report and in our annual report filed on Form 10-K for the year ended December 31, 2022.

Results of Operations


	Three Months Ended March 31,
	2023		2022
Net Production Data:	(In thousands except per unit amounts)
Natural gas (MMcf)	127,067		114,906
Oil (MBbls)	27		21
Natural gas equivalent (MMcfe)	127,226		115,035
Revenues:
Natural gas sales	$	378,032	$	522,957
Oil sales	1,942		1,884
Total natural gas and oil sales	$	379,974	$	524,841
Expenses:
Production and ad valorem taxes	$	14,906	$	13,820
Gathering and transportation	$	45,574	$	32,093
Lease operating	$	34,830	$	26,186
Exploration	$	1,775	$	1,021
Average Sales Price:
Natural gas (per Mcf)	$	2.98	$	4.55
Oil (per Bbl)	$	71.93	$	89.71
Average equivalent (Mcfe)	$	2.99	$	4.56
Expenses ($ per Mcfe):
Production and ad valorem taxes	$	0.12	$	0.12
Gathering and transportation	$	0.36	$	0.28
Lease operating	$	0.27	$	0.23
Gas Services
Gas services revenue	$	109,604	$	—
Gas services expense	$	101,295	$	—

Revenues –

Natural gas and oil sales of $380.0 million for the first quarter of 2023 decreased by $144.9 million (28%) as compared to $524.8 million for the first quarter of 2022. The decrease was primarily due to lower natural gas prices. Our natural gas production for the first quarter of 2023 increased 11% to 127.1 billion cubic feet ("Bcf") (1.4 Bcf per day), and was sold at an average price of $2.98 per Mcf. Our natural gas production for the first quarter of 2022 was 114.9 Bcf (1.3 Bcf per day) and was sold at an average price of $4.55 per Mcf.

We utilize natural gas price derivative financial instruments to manage our exposure to changes in prices of natural gas and to protect returns on investment from our drilling activities. The following table presents our natural gas prices before and after the effect of cash settlements of our derivative financial instruments:


	Three Months Ended March 31,
	2023		2022
Average Realized Natural Gas Price:
Natural gas, per Mcf	$	2.98	$	4.55
Cash settlements on derivative financial instruments, per Mcf	0.08		(1.02)
Price per Mcf, including cash settlements on derivative financial instruments	$	3.06	$	3.53

Gas service revenues of $109.6 million for the three months ended March 31, 2023 included sales of natural gas purchased from unaffiliated third parties for resale and fees received from unaffiliated third parties for natural gas transportation and treating services. These activities commenced in April 2022 with the acquisition of a pipeline and gas treating plant and the opportunity to utilize our excess transport capacity in North Louisiana.

Costs and Expenses –

Our production and ad valorem taxes increased $1.1 million (8%) to $14.9 million for the first quarter of 2023 from $13.8 million in the first quarter of 2022. The increase was primarily related to higher production tax rates enacted in Louisiana during the second half of 2022 and the 11% increase in production in the first quarter of 2023.

Gathering and transportation costs for the first quarter of 2023 increased $13.5 million (42%) to $45.6 million as compared to $32.1 million in the first quarter of 2022. The increase is due to production growth in areas with higher average gathering and transportation rates.

Our lease operating expense of $34.8 million ($0.27 per Mcfe) for the first quarter of 2023 increased $8.6 million (33%) from lease operating expense of $26.2 million ($0.23 per Mcfe) for the first quarter of 2022. The increase was due primarily to increased personnel and other production costs.

Gas service expenses were $101.3 million for the three months ended March 31, 2023, which include the cost of unaffiliated third party natural gas purchased for resale and the operating expenses of the pipeline and natural gas treating plant acquired in April 2022.

Depreciation, depletion and amortization ("DD&A") increased $27.3 million to $134.0 million in the first quarter of 2023 from $106.7 million in the first quarter of 2022. Our DD&A per equivalent Mcf produced was $1.05 per Mcfe for the quarter ended March 31, 2023 as compared to $0.93 for the quarter ended March 31, 2022. The increase in the DD&A rate was primarily due to higher drilling and completion costs incurred for wells turned to sales in the first quarter of 2023.

General and administrative expenses, which are reported net of overhead reimbursements, increased to $12.4 million for the first quarter of 2023 as compared to $8.2 million in the first quarter of 2022. The increases were primarily related to higher personnel costs.

We use derivative financial instruments as part of our price risk management program to protect our capital investments. During the quarter ended March 31, 2023, we had net gains related to our derivative financial instruments of $66.4 million, as compared to net losses on derivative financial instruments of $437.5 million during the quarter ended March 31, 2022. Realized net gains from our oil and natural gas price risk management program were $10.4 million for the quarter ended March 31, 2023 as compared to realized net losses of $117.2 million for the quarter ended March 31, 2022.

Interest expense was $38.3 million and $46.5 million for the quarters ended March 31, 2023 and 2022, respectively. The decrease in interest expense is due primarily to the early retirements of senior notes in May and June 2022 and the repayment of outstanding borrowings under the bank credit facility in 2022.

Income taxes for the quarter ended March 31, 2023 and 2022 were a provision of $39.7 million and a benefit of $31.6 million, respectively. Income tax expense for the three months ended March 31, 2023 reflects an effective tax rate of 22.9% and the income tax benefit for the three months ended March 31, 2022 reflects an effective tax rate of 22.1%. The difference between the federal statutory tax rate of 21% and our effective rate is primarily attributable to the impact of state income taxes and revisions to the estimated future utilization of federal and state net operating loss carryforwards.

We reported net income available to common stockholders of $134.5 million or $0.49 per diluted share, for the quarter ended March 31, 2023 which included a $66.4 million net gain from derivative financial instruments. Income from operations for the first quarter of 2023 was $145.6 million. We reported net loss available to common stockholders of $115.7 million or $0.50 per share for the quarter ended March 31, 2022.

Cash Flows, Liquidity and Capital Resources

Cash Flows

The following table summarizes sources and uses of cash and cash equivalents:


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Sources of cash and cash equivalents:
Operating activities	$	386,364	$	285,618


Proceeds from asset sales	130		45

Total	$	386,494	$	285,663

Uses of cash and cash equivalents:
Capital expenditures	$	372,637	$	214,856

Repayments of bank credit facility, net of borrowings	—		85,000
Common stock dividends	34,688		—
Preferred stock dividends	—		4,315
Other	144		18
Total	$	407,469	$	304,189

Cash flows from operating activities. Net cash provided by our operating activities increased $100.7 million (35%) to $386.4 million in the first three months of 2023 from $285.6 million in the same period in 2022.

Capital expenditures. The increase in capital expenditures of $157.8 million is primarily due to our higher drilling and completion activity in the first quarter of 2023 and $40.7 million of unproved property acquisitions.

Our capital expenditures are summarized in the following table:


	Three Months Ended March 31,
	2023		2022
	(In thousands)
Acquisitions:
Proved property	$	—	$	274
Unproved property	40,695		3,631
Exploration and development:
Development leasehold costs	8,743		4,632
Exploratory drilling and completion costs	29,690		11,557
Drilling and completion costs	280,176		189,048
Other development costs	6,097		18,612
Asset retirement obligations	30		381
Total exploration and development	365,431		228,135
Other property and equipment	4,543		22
Total capital expenditures	$	369,974	$	228,157
Change in accrued capital expenditures	1,009		(14,499)
Prepaid drilling costs	1,684		1,579
Change in asset retirement obligations	(30)		(381)
Total cash capital expenditures	$	372,637	$	214,856

We drilled 44 (16.3 net) wells and completed 29 (12.8 net) Haynesville and Bossier shale wells during the first three months of 2023. We currently expect to spend an additional $750 million to $850 million in the remaining nine months of 2023 on drilling, completion, infrastructure and other activity.

Liquidity and Capital Resources

As of March 31, 2023, we had $1.5 billion of liquidity, comprised of unused borrowing capacity under our bank credit facility and $33.7 million of cash and cash equivalents on hand. Our short and long-term capital requirements consist primarily of funding our development and exploration activities, acquisitions, payments of contractual obligations and debt service.

We expect to fund our future development and exploration activities with future operating cash flow and borrowings under our bank credit facility. The timing of most of our future capital expenditures is discretionary because of the limited number of material long-term capital expenditure commitments. Consequently, we have a significant degree of flexibility to adjust the level of our capital expenditures as circumstances warrant. If our plans or assumptions change or our assumptions prove to be inaccurate, we may be required to seek additional capital, including debt or equity financing. We cannot provide any assurance that we will be able to obtain such capital, or if such capital is available, that we will be able to obtain it on acceptable terms.

We do not have a specific acquisition budget for the remainder of 2023 because the timing and size of acquisitions are unpredictable. We intend to use our cash flows from operations, borrowings under our bank credit facility, or other debt or equity financings to the extent available, to finance such acquisitions. The availability and attractiveness of these sources of financing will depend upon a number of factors, some of which will relate to our financial condition and performance and some of which will be beyond our control, such as prevailing interest rates, natural gas and oil prices and other market conditions. Lack of access to the debt or equity markets due to general economic conditions could impede our ability to complete acquisitions.

At March 31, 2023, we had no borrowings outstanding under our bank credit facility. Aggregate commitments under our bank credit facility are $1.5 billion, which matures on November 15, 2027. Borrowings under the bank credit facility are subject to a borrowing base, which was redetermined on April 20, 2023 and currently set at $2.0 billion. The borrowing base is re-determined on a semi-annual basis and upon the occurrence of certain other events. Borrowings under the bank credit facility are secured by substantially all of our assets and those of our subsidiaries and bear interest at our option, at either adjusted SOFR plus 1.75% to 2.75% or an alternate base rate plus 0.75% to 1.75%, in each case depending on the utilization of the borrowing base. We also pay a commitment fee of 0.375% to 0.50% on the unused portion of the borrowing base. The bank credit facility places certain restrictions upon our and our subsidiaries' ability to, among other things, incur additional indebtedness, pay cash dividends, repurchase common stock, make certain loans, investments and divestitures and redeem the senior notes. The only financial covenants are the maintenance of a leverage ratio of less than 3.5 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0. We were in compliance with the covenants as of March 31, 2023.

Income Taxes

At March 31, 2023, we had $767.5 million in U.S. federal net operating loss ("NOL") carryforwards and $1.5 billion in certain state NOL carryforwards. As a result of the change of control in August 2018, our ability to use NOLs to reduce taxable income is generally limited to an annual amount based on the fair market value of our stock immediately prior to the ownership change multiplied by the long-term tax-exempt interest rate. Our NOLs are estimated to be limited to $3.3 million a year as a result of this limitation. In addition to this limitation, IRC Section 382 provides that a corporation with a net unrealized built-in gain immediately before an ownership change may increase its limitation by the amount of recognized built-in gain recognized during a recognition period, which is generally the five-year period immediately following an ownership change. Based on the fair market value of our common stock immediately prior to the ownership change, we believe that we have a net unrealized built-in gain which will increase the Section 382 limitation during the five-year recognition period from 2018 to 2023 by $147.7 million.

NOLs that exceed the Section 382 limitation in any year continue to be allowed as carryforwards until they expire and can be used to offset taxable income for years within the carryover period subject to the limitation in each year. NOLs incurred prior to 2018 generally have a 20-year life until they expire. NOLs generated in 2018 and after would be carried forward indefinitely. Our use of new NOLs arising after the date of an ownership change would not be affected by the 382 limitation. If we do not generate a sufficient level of taxable income prior to the expiration of the pre-2018 NOL carryforward periods, then we will lose the ability to apply those NOLs as offsets to future taxable income. We estimate that $767.2 million of the U.S. federal NOL carryforwards and $1.2 billion of the estimated state NOL carryforwards will expire unused.

ITEM 3: QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

Oil and Natural Gas Prices

Our financial condition, results of operations and capital resources are highly dependent upon the prevailing market prices of natural gas and oil. These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors, some of which are beyond our control. Factors influencing natural gas and oil prices include the level of global demand for oil, the foreign supply of natural gas and oil, the effect of the war in Ukraine and the geopolitical response to Russia's invasion, the establishment of and compliance with production quotas by oil exporting countries, weather conditions that determine the demand for natural gas, the price and availability of alternative fuels and overall economic conditions. It is impossible to predict future natural gas and oil prices with any degree of certainty. Sustained weakness in natural gas and oil prices may adversely affect our financial condition and results of operations, and may also reduce the amount of natural gas and oil reserves that we can produce economically. Any reduction in our natural gas and oil reserves, including reductions due to price fluctuations, can have an adverse effect on our ability to obtain capital for our exploration and development activities. Similarly, any improvements in natural gas and oil prices can have a favorable impact on our financial condition, results of operations and capital resources.

As of March 31, 2023, we had natural gas collars to hedge approximately 107.4 Bcf of our 2023 natural gas production with an average floor price of $3.00 per MMBtu and an average ceiling price of $10.22 per MMBtu. None of our derivative contracts have margin requirements or collateral provisions that could require funding prior to the scheduled cash settlement date.

An increase of 10% in the market price of natural gas on March 31, 2023 would decrease the fair value of our natural gas collars by approximately $14.2 million. A decrease of 10% in the market price of natural gas on March 31, 2023 would increase the fair value of our natural gas collars by approximately $12.6 million. The impact of hypothetical changes in market prices of natural gas on our natural gas derivative financial instruments discussed above does not include the offsetting impact that the same hypothetical changes in market prices of natural gas may have on our physical sales of natural gas. Since our outstanding natural gas derivative financial instruments hedge only a portion of our forecasted physical gas production, a positive or negative impact to the fair value of our natural gas derivative financial instruments would be partially offset by our physical sales of natural gas.

Interest Rates

At March 31, 2023, we had approximately $2.2 billion principal amount of long-term debt outstanding. $965.0 million of our long-term debt bear interest at a fixed rate of 5.875% and $1.22 billion of our long-term debt bear interest at a fixed rate of 6.75%. As of March 31, 2023, the fair market value of the 5.875% senior notes due in 2030 and the 6.75% senior notes due in 2029 was $822.7 million and $1.1 billion, respectively, based on the market price of approximately 85% and 90%, respectively, of the face amount of such debt. At March 31, 2023, we had no outstanding balance under our bank credit facility, which is subject to variable rates of interest that are tied to SOFR or the corporate base rate, at our option. Any increase in these interest rates would have an adverse impact on our results of operations and cash flow.

ITEM 4: CONTROLS AND PROCEDURES

As of March 31, 2023, we carried out an evaluation, under the supervision and with the participation of our chief executive officer and chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934). Based on this evaluation, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures were effective as of March 31, 2023 to provide reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms, and to provide reasonable assurance that information required to be disclosed by us is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. There were no changes in our internal controls over financial reporting (as such term is defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) that occurred during the three months ended March 31, 2023 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

PART II — OTHER INFORMATION

ITEM 6: EXHIBITS


Exhibit No.						Description

31.1*						Section 302 Certification of the Chief Executive Officer.

31.2*						Section 302 Certification of the Chief Financial Officer.

32.1†						Certification for the Chief Executive Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.

32.2†						Certification for the Chief Financial Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS*						Inline XBRL Instance Document

101.SCH*						Inline XBRL Schema Document

101.CAL*						Inline XBRL Calculation Linkbase Document

101.LAB*						Inline XBRL Labels Linkbase Document

101.PRE*						Inline XBRL Presentation Linkbase Document

101.DEF*						Inline XBRL Definition Linkbase Document

104*						Cover Page Interactive Data File (embedded within the Inline XBRL document)

_____________________________

* Filed herewith.

† Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


			COMSTOCK RESOURCES, INC.

Date: May 4, 2023			/s/ M. JAY ALLISON
			M. Jay Allison, Chairman and Chief Executive Officer
			(Principal Executive Officer)

Date: May 4, 2023			/s/ ROLAND O. BURNS
			Roland O. Burns, President, Chief Financial Officer and Secretary
			(Principal Financial and Accounting Officer)

Positive
Negative
Uncertain
Constraining
Legalese
Litigous
Readability	H.S. freshman Avg


			Page
PART I. Financial Information

Item 1. Financial Statements (Unaudited):
Consolidated Balance Sheets as of March 31, 2023 and December 31, 2022			4
Consolidated Statements of Operations – for the three months ended March 31, 2023 and 2022			5
Consolidated Statements of Stockholders' Equity – for the three months ended March 31, 2023 and 2022			6
Consolidated Statements of Cash Flows – for the three months ended March 31, 2023 and 2022			7
Notes to Consolidated Financial Statements			8

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			18

Item 3. Quantitative and Qualitative Disclosure About Market Risk			22

Item 4. Controls and Procedures			22

PART II. Other Information

Item 6. Exhibits			23

Comstock Resources (CRK) 10-Q2023 Q1 Quarterly report

Content analysis