COMSTOCK RESOURCES INC - Quarter Report: 2021 June (Form 10-Q)

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 June 30, 2021


☐			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 ☐

Emerging growth company ☐

Accelerated filer x

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 August 4, 2021 was 232,850,477.

COMSTOCK RESOURCES, INC.

QUARTERLY REPORT

For the Quarter Ended June 30, 2021

INDEX


			Page
PART I. Financial Information

Item 1. Financial Statements (Unaudited):
Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020			4
Consolidated Statements of Operations – for the three months and six months ended June 30, 2021 and 2020			5
Consolidated Statements of Stockholders' Equity – for the three months and six months ended June 30, 2021 and 2020			6
Consolidated Statements of Cash Flows – for the six months ended June 30, 2021 and 2020			7
Notes to Consolidated Financial Statements			8

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			19

Item 3. Quantitative and Qualitative Disclosure About Market Risk			23

Item 4. Controls and Procedures			23

PART II. Other Information

Item 6. Exhibits			24

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


	June 30, 2021		December 31, 2020
ASSETS	(In thousands)
Cash and cash equivalents	$	19,727	$	30,272
Accounts receivable:
Oil and gas sales	144,358		125,016
Joint interest operations	23,781		14,615
From affiliates	17,837		6,155
Derivative financial instruments	10,765		8,913

Other current assets	8,410		14,839
Total current assets	224,878		199,810
Property and equipment:
Oil and natural gas properties, successful efforts method:
Proved	4,981,955		4,647,188
Unproved	339,278		332,765
Other	6,731		6,858
Accumulated depreciation, depletion and amortization	(1,132,191)		(902,261)
Net property and equipment	4,195,773		4,084,550
Goodwill	335,897		335,897

Derivative financial instruments	830		661
Operating lease right-of-use assets	6,833		3,025
Other assets	37		40
	$	4,764,248	$	4,623,983
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable	$	292,998	$	259,284
Accrued costs	105,210		133,019
Operating leases	2,190		2,284
Derivative financial instruments	255,127		47,005
Total current liabilities	655,525		441,592
Long-term debt	2,847,309		2,517,149
Deferred income taxes	99,245		200,583
Derivative financial instruments	14,157		2,364
Long-term operating leases	4,674		740
Reserve for future abandonment costs	20,748		19,290
Other non-current liabilities	180		492
Total liabilities	3,641,838		3,182,210
Commitments and contingencies
Mezzanine equity:
Series B 10% Convertible Preferred stock — 5,000,000 shares authorized, 175,000 shares issued and outstanding at June 30, 2021 and December 31, 2020, respectively	175,000		175,000
Stockholders' equity:
Common stock—$0.50 par, 400,000,000 shares authorized, 232,850,477 and 232,414,718 shares issued and outstanding at June 30, 2021 and December 31, 2020, respectively	116,425		116,206
Additional paid-in capital	1,098,300		1,095,384
Accumulated earnings (deficit)	(267,315)		55,183
Total stockholders' equity	947,410		1,266,773
	$	4,764,248	$	4,623,983

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(In thousands, except per share amounts)
Revenues:
Natural gas sales	$	321,520	$	172,362	$	645,480	$	379,601
Oil sales	22,173		7,173		38,698		25,812
Total oil and gas sales	343,693		179,535		684,178		405,413
Operating expenses:
Production and ad valorem taxes	10,141		9,569		19,793		17,970
Gathering and transportation	31,736		26,590		61,194		55,001
Lease operating	26,011		27,820		50,574		53,698
Depreciation, depletion and amortization	121,446		103,347		230,574		213,772
General and administrative	7,872		8,298		15,900		17,017
Exploration	—		—		—		27
Gain on sale of assets	(9)		—		(79)		—
Total operating expenses	197,197		175,624		377,956		357,485

Operating income	146,496		3,911		306,222		47,928
Other income (expenses):
Gain (loss) from derivative financial instruments	(223,958)		(12,298)		(245,707)		49,601
Other income (expense)	530		(9)		811		304

Interest expense	(56,880)		(52,064)		(120,691)		(104,874)
Loss on early retirement of debt	(114,060)		(861)		(352,599)		(861)
Total other expenses	(394,368)		(65,232)		(718,186)		(55,830)
Loss before income taxes	(247,872)		(61,321)		(411,964)		(7,902)
Benefit from income taxes	68,177		11,445		98,144		54
Net loss	(179,695)		(49,876)		(313,820)		(7,848)
Preferred stock dividends and accretion	(4,363)		(10,126)		(8,678)		(22,198)
Net loss available to common stockholders	$	(184,058)	$	(60,002)	$	(322,498)	$	(30,046)

Net loss per share:
Basic	$	(0.80)	$	(0.29)	$	(1.39)	$	(0.15)
Diluted	$	(0.80)	$	(0.29)	$	(1.39)	$	(0.15)
Weighted average shares outstanding:
Basic	231,428		208,904		231,403		198,910
Diluted	231,428		208,904		231,403		198,910

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, 2020	190,007	$	95,003	$	909,423	$	138,596	$	1,143,022
Stock-based compensation	(24)	(12)		1,442		—		1,430
Income tax withholdings on equity awards	(2)	(1)		(14)		—		(15)
Net income	—	—		—		42,028		42,028
Preferred stock accretion	—	—		—		(2,500)		(2,500)
Payment of preferred dividends	—	—		—		(9,572)		(9,572)
Balance at March 31, 2020	189,981	$	94,990	$	910,851	$	168,552	$	1,174,393
Stock-based compensation	507	254		1,298		—		1,552
Issuances of common stock	42,092	21,046		190,592		—		211,638
Stock issuance costs	—	—		(10,079)		—		(10,079)
Net loss	—	—		—		(49,876)		(49,876)
Preferred stock accretion	—	—		—		(2,917)		(2,917)
Payment of preferred dividends	—	—		—		(7,210)		(7,210)
Balance at June 30, 2020	232,580	$	116,290	$	1,092,662	$	108,549	$	1,317,501







Balance at January 1, 2021	232,415	$	116,206	$	1,095,384	$	55,183	$	1,266,773
Stock-based compensation	(4)	—		1,690		—		1,690
Stock issuance costs	—	—		(30)		—		(30)
Net loss	—	—		—		(134,125)		(134,125)
Payment of preferred dividends	—	—		—		(4,315)		(4,315)
Balance at March 31, 2021	232,411	$	116,206	$	1,097,044	$	(83,257)	$	1,129,993
Stock-based compensation	472	235		1,564		—		1,799
Income tax withholdings on equity awards	(33)	(16)		(182)		—		(198)
Stock issuance costs	—	—		(126)		—		(126)
Net loss	—	—		—		(179,695)		(179,695)
Payment of preferred dividends	—	—		—		(4,363)		(4,363)
Balance at June 30, 2021	232,850	$	116,425	$	1,098,300	$	(267,315)	$	947,410

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
	2021		2020
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(313,820)	$	(7,848)
Adjustments to reconcile net loss to net cash provided by operating activities:
Deferred income taxes	(101,281)		(206)
Exploration	—		27
Gain on sale of assets	(79)		—
Depreciation, depletion and amortization	230,574		213,772
(Gain) loss on derivative financial instruments	245,707		(49,601)
Cash settlements of derivative financial instruments	(27,813)		98,703
Amortization of debt discount and issuance costs	13,575		14,726
Stock-based compensation	3,489		2,982
Loss on early retirement of debt	352,599		861
(Increase) decrease in accounts receivable	(40,190)		83,172
(Increase) decrease in other current assets	5,528		(2,803)
Increase (decrease) in accounts payable and accrued expenses	17,294		(87,694)
Net cash provided by operating activities	385,583		266,091
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(338,779)		(233,874)

Proceeds from sales of assets	211		—
Net cash used for investing activities	(338,568)		(233,874)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on bank credit facility	180,000		102,000
Repayments on bank credit facility	(205,000)		(552,000)
Issuance of Senior Notes	2,222,500		450,000
Retirement of Senior Notes	(2,210,626)		—
Issuance of common stock	—		206,626
Redemption of Series A Preferred Stock	—		(210,000)
Preferred stock dividends paid	(8,678)		(16,782)
Debt and stock issuance costs	(35,558)		(18,983)
Income tax withholdings on equity awards	(198)		(15)
Net cash used for financing activities	(57,560)		(39,154)
Net decrease in cash and cash equivalents	(10,545)		(6,937)
Cash and cash equivalents, beginning of period	30,272		18,532
Cash and cash equivalents, end of period	$	19,727	$	11,595

The accompanying notes are an integral part of these statements.

COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(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 June 30, 2021, 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. Certain amounts in prior periods have been reclassified to conform with current period presentation.

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, 2020.

The results of operations for the period through June 30, 2021 are not necessarily an indication of the results expected for the full year.

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 leasehold are capitalized.

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. Exploratory drilling costs are initially capitalized as proved property but charged to expense if and when the well is determined not to have found commercial quantities of proved oil and gas reserves. Exploratory drilling costs are evaluated within a one-year period after the completion of drilling.

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 June 30, 2021 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 1st 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 $6.8 million related to its corporate office lease, certain office equipment and leased vehicles used in oil and gas operations 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 operations routinely change due to changes in commodity prices, demand for oil and natural gas, and the overall operating and economic environment. Comstock accordingly manages the terms of its contracts for drilling rigs so as to allow for maximum flexibility in responding to these changing conditions. The Company's 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. Accordingly, the Company has elected not to recognize right-of-use lease assets for these rig contracts. The costs associated with drilling rig 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 and six months ended June 30, 2021 were as follows:


	Three Months Ended June 30, 2021		Six Months Ended June 30, 2021
	(In thousands)
Operating lease cost included in general and administrative expense	$	435	$	864
Operating lease cost included in lease operating expense	190		422
Short-term lease cost (drilling rig costs included in proved oil and gas properties)	7,659		19,243
	$	8,284	$	20,529

Cash payments for operating leases associated with right-of-use assets included in cash provided by operating activities were $625 thousand and $1.3 million for the three months and six months ended June 30, 2021.

As of June 30, 2021, expected future payments related to contracts that contain operating leases were as follows:


	(In thousands)
July 1 to December 31, 2021	$	1,141
2022	2,317
2023	1,983
2024	1,733
2025	1
Total lease payments	7,175
Imputed interest	(310)
Total lease liability	$	6,865

The weighted average term of these operating leases was 3.3 years and the weighted average interest rate used in lease computations was 2.8%. As of June 30, 2021, the Company also had expected future payments for contracted drilling services of $4.8 million.

Accrued Costs

Accrued costs at June 30, 2021 and December 31, 2020 consisted of the following:


	As of June 30, 2021		As of December 31, 2020
	(In thousands)
Accrued interest payable	$	30,549	$	67,265
Accrued capital expenditures	25,744		24,959
Accrued transportation costs	24,379		25,353
Accrued employee compensation	7,562		7,519
Accrued ad valorem taxes	6,000		—
Accrued income and other taxes	5,661		2,168
Accrued lease operating expenses	2,354		3,466
Other	2,961		2,289
	$	105,210	$	133,019

Reserve for Future Abandonment Costs

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


	Six Months Ended June 30,
	2021		2020
	(In thousands)
Reserve for future abandonment costs at beginning of period	$	19,290	$	18,151
New wells placed on production	862		289

Liabilities settled and assets disposed of	(6)		(27)
Accretion expense	602		581
Reserve for future abandonment costs at end of period	$	20,748	$	18,994

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. All of Comstock's natural gas derivative financial instruments, except for certain basis swaps, are tied to the Henry Hub-NYMEX price index and all of its crude oil derivative financial instruments are tied to the WTI-NYMEX index price. The Company had the following oil and natural gas price derivative financial instruments at June 30, 2021:


	Future Production Period
	Six Months Ending December 31, 2021		Year Ending December 31, 2022		Year Ending December 31, 2023	Total
Natural Gas Swap Contracts:
Volume (MMBtu)	105,340,000	(1)	74,750,000		—	180,090,000
Average Price per MMBtu	$2.53	(1)	$2.75		—	$2.62
Natural Gas Collar Contracts:
Volume (MMBtu)	74,210,000		109,450,000		4,500,000	188,160,000
Price per MMBtu:
Average Ceiling	$3.04		$3.44		$3.67	$3.29
Average Floor	$2.47		$2.52		$2.50	$2.50






Natural Gas Swaptions Contracts:
Volume (MMBtu)	—		43,800,000	(2)	—	43,800,000	(2)
Average Price per MMBtu	—		$2.51	(2)	—	$2.51	(2)
Natural Gas Basis Swap Contracts:
Volume (MMBtu)	7,360,000	(3)	10,950,000	(3)	—	18,310,000	(3)
Average Price per MMBtu	($0.12)		($0.16)		—	($0.14)
Crude Oil Collar Contracts:
Volume (Bbls)	276,000		—		—	276,000
Price per Bbl:
Average Ceiling	$51.67		—		—	$51.67
Average Floor	$41.67		—		—	$41.67

_____________________________

(1)For the six months ending December 31, 2021, natural gas price swap contracts include 22,080,000 MMBtu at an average price of $2.51 that are part of certain natural gas price swaption contracts which include a call to extend the price swap by the counterparty as described in (2) below.

(2)The counterparty has the right to exercise a call option to enter into a price swap with the Company on 43,800,000 MMBtu in 2022 at an average price $2.51. The call option expires for 36,500,000 MMBtu at an average price of $2.52 in October 2021 and 7,300,000 MMBtu at an average price of $2.50 in November 2021.

(3)Contracts fix the differential between NYMEX Henry Hub and the Houston Ship Channel indices.

The Company has interest rate swap agreements that fix LIBOR at 0.33% for $500.0 million of its floating rate long-term debt. These contracts settle monthly through April 2023. The fair value of these contracts was a net liability of $1.0 million at June 30, 2021.

None of the Company's derivative contracts were designated as cash flow hedges. The aggregate fair value of the Company's derivative instruments are presented on a gross basis in the accompanying consolidated balance sheets. The classification of derivative financial instruments between assets and liabilities, consists of the following:


Type	Consolidated Balance Sheet Location	June 30, 2021		December 31, 2020
		(in thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	6,419	$	8,913
Oil price derivatives	Derivative Financial Instruments – current	4,346		—
		$	10,765	$	8,913

Natural gas price derivatives	Derivative Financial Instruments – long-term	$	798	$	661
Interest rate derivatives	Derivative Financial Instruments – long-term	32		—
		$	830	$	661

Liability Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	244,304	$	45,158
Oil price derivatives	Derivative Financial Instruments – current	9,828		831
Interest rate derivatives	Derivative Financial Instruments – current	995		1,016
		$	255,127	$	47,005

Natural gas price derivatives	Derivative Financial Instruments – long-term	$	14,157	$	1,308

Interest rate derivatives	Derivative Financial Instruments – long-term	—		1,056
		$	14,157	$	2,364

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 June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(In thousands)
Natural gas price derivatives	$	(219,845)	$	(5,140)	$	(238,722)	$	37,835
Oil price derivatives	(3,989)		(4,406)		(7,533)		14,518
Interest rate derivatives	(124)		(2,752)		548		(2,752)
	$	(223,958)	$	(12,298)	$	(245,707)	$	49,601

Subsequent to June 30, 2021, the Company entered into natural gas swap contracts to hedge 2,750,000 MMBtu of natural gas production from April 2022 to December 2022 at an average price of $3.00 per MMBtu. The Company also entered into natural gas collar contracts to hedge 6,350,000 MMBtu of natural gas production from January 2022 to December 2022 at an average floor price of $2.85 per MMBtu and an average ceiling price of $5.13 per MMBtu.

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 $1.8 million and $1.6 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 June 30, 2021 and 2020, respectively, and $3.5 million and $3.0 million for the six months ended June 30, 2021 and 2020, respectively.

On June 8, 2021, the Company granted 473,162 shares of restricted stock to its employees and directors with a per share value of $6.05. As of June 30, 2021, Comstock had 1,305,368 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $5.96 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $5.7 million as of June 30, 2021 is expected to be recognized over a period of 2.1 years.

On June 8, 2021, the Company granted 220,929 PSUs to its officers with a per unit value of $8.56. As of June 30, 2021, Comstock had 1,357,417 PSUs outstanding at a weighted average grant date fair value of $9.21 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 2,714,834 shares of common stock. Total unrecognized compensation cost related to these grants of $5.0 million as of June 30, 2021 is expected to be recognized over a period of 2.0 years.

Revenue Recognition

Comstock produces oil and natural gas 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. Payment is reasonably assured upon delivery of production. All sales 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 oil and natural gas 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 oil and natural gas routinely fluctuate based on changes in these factors. 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. 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 oil or natural gas 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 June 30, 2021. Sales of oil and natural gas generally occur at or near the wellhead. When sales of oil and gas occur at locations other than the wellhead, the Company accounts for costs incurred to transport the production to the delivery point as gathering and transportation expenses. The Company recognized accounts receivable of $144.4 million as of June 30, 2021 from customers 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 oil and gas or participants in oil and gas wells for which the Company serves as the operator. Generally, operators of oil and gas wells have the right to offset future revenues against unpaid charges related to operated wells. Oil and gas sales are generally unsecured. Comstock assesses the collectibility 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 six months ended June 30, 2021 and 2020.

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 benefit (provision):


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(In thousands)

Current - State	$	(3,001)	$	(88)	$	(3,137)	$	(149)
Deferred - Federal	58,044		13,520		92,963		2,017
Deferred - State	13,134		(1,987)		8,318		(1,814)
	$	68,177	$	11,445	$	98,144	$	54

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


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
Tax at statutory rate	21.0	%	21.0	%	21.0	%	21.0	%
Tax effect of:
Valuation allowance on deferred tax assets	10.9		(0.8)		(7.6)		5.2
State income taxes, net of federal benefit	4.1		(2.5)		1.3		(30.0)
Nondeductible stock-based compensation	0.3		0.8		0.1		2.9
Change in Louisiana tax law	(8.8)		—		9.0		—
Other	—		0.2		—		1.6
Effective tax rate	27.5	%	18.7	%	23.8	%	0.7	%

Effective June 30, 2021, the State of Louisiana enacted a new law, which provides that all NOL deductions claimed on any corporate income tax return filed on or after January 1, 2022 for NOLs relating to loss years on or after January 1, 2001 may be carried forward indefinitely, until such losses are fully recovered. The restoration of future NOLs previously expected to lapse due to limitation rules now serve as a tax benefit to the Company, subject to other limitations.

The Company's federal income tax returns for the years subsequent to December 31, 2016 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, 2013. The Company currently believes that all other significant filing positions are highly certain and that all of its other significant income tax 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.

The Company's natural gas price swap agreements, basis swap agreements, interest rate swap agreements and its crude oil and natural gas price collars were not traded on a public exchange, and their value is determined utilizing a discounted cash flow model based on inputs that are readily available in public markets and, accordingly, the valuation of these derivative financial instruments, is categorized as a Level 2 measurement. The Company's natural gas swaption agreements are measured at fair value using a third-party pricing service, categorized as a Level 3 measurement.

The following is a reconciliation of the beginning and ending balances for derivative instruments classified as Level 3 in the fair value hierarchy:


	Six Months Ended June 30,
	2021		2020
	(In thousands)
Balance at beginning of year	$	(22,588)	$	4,351
Total gain (loss) included in earnings	(30,262)		11,454
Settlements, net	5,402		(22,585)
Transfers out of Level 3	(6,418)		—
Balance at end of period	$	(53,866)	$	(6,780)

Fair Values – Reported

The following presents the carrying amounts and the fair values of the Company's financial instruments as of June 30, 2021 and December 31, 2020:


	June 30, 2021				December 31, 2020
	Carrying Value		Fair Value		Carrying Value		Fair Value
Assets:	(In thousands)
Derivative financial instruments (1)	$	11,595	$	11,595	$	9,574	$	9,574
Liabilities:
Derivative financial instruments (1)	$	269,284	$	269,284	$	49,369	$	49,369
Bank credit facility (2)	$	475,000	$	475,000	$	500,000	$	500,000
7.50% senior notes due 2025 (3)	$	191,774	$	253,565	$	473,728	$	628,691
9.75% senior notes due 2026 (3)	$	—	$	—	$	1,577,824	$	1,769,625
6.75% senior notes due 2029 (3)	$	1,257,257	$	1,328,125	$	—	$	—
5.875% senior notes due 2030 (3)	$	965,000	$	984,300	$	—	$	—

______________

(1)The Company's natural gas price swaps and basis swap agreements, its interest rate swap agreements and its crude oil and natural gas price collars are classified as Level 2 and measured at fair value using a market approach using third party pricing services and other active markets or broker quotes that are readily available in the public markets. The Company's natural gas swaption contracts provide the counterparty the right, but not the obligation, to extend terms of an existing swap on predetermined dates. Due to subjectivity of the inputs used to value the counterparty rights in the contracts, these contracts are classified as Level 3 in the fair value hierarchy.

(2)The carrying value of our floating rate debt outstanding approximates fair value.

(3)The fair value of the Company's fixed rate debt was based on quoted prices as of June 30, 2021 and December 31, 2020, 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 June 30, 2021 and December 31, 2020, 1,305,368 and 1,038,006 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 June 30,		Six Months Ended June 30,
	2021	2020	2021	2020
	(in thousands)
Unvested restricted stock	1,091	1,184	1,063	1,135

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 June 30,		Six Months Ended June 30,
	2021	2020	2021	2020
	(In thousands, except per unit amounts)
Weighted average PSUs	1,192	976	1,165	951
Weighted average grant date fair value per unit	$9.21	$9.33	$9.21	$9.33

The Company redeemed all of the shares of Series A Convertible Preferred Stock on May 19, 2020. The Series B Convertible Preferred Stock became convertible into an aggregate of 43,750,000 shares of common stock on July 16, 2020 at a conversion price of $4.00 per share. The dilutive effect of preferred stock is computed using the if-converted method as if conversion of the preferred shares had occurred at the earlier of the date of issuance or the beginning of the period. Weighted average shares of convertible preferred stock outstanding were as follows:


	Three Months Ended June 30,		Six Months Ended June 30,
	2021	2020	2021	2020
	(In thousands)
Weighted average convertible preferred stock	43,750	72,019	43,750	84,135

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.

Basic and diluted per share amounts are the same for the three months and six months ended June 30, 2021 and 2020 due to the net losses in the periods.

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 six months ended June 30, 2021 and 2020, respectively, were as follows:


	Six Months Ended June 30,
	2021		2020
	(In thousands)
Cash payments for:
Interest payments	$	204,615	$	90,552

Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	785	$	(29,078)
Liabilities assumed in exchange for right-of-use lease assets	$	4,998	$	1,505
Non-cash financing activities include:
Retirement of debt in exchange for common stock	$	—	$	(4,151)
Issuance of common stock in exchange for debt	$	—	$	5,012

(2) LONG-TERM DEBT

At June 30, 2021, long-term debt was comprised of the following:


	(In thousands)
7.50% Senior Notes due 2025:
Principal	$	244,400
Discount, net of amortization	(52,626)
6.75% Senior Notes due 2029:
Principal	1,250,000
Premium, net of amortization	7,257
5.875% Senior Notes due 2030:
Principal	965,000
Bank Credit Facility:
Principal	475,000
Debt issuance costs, net of amortization	(41,722)
	$	2,847,309

As of June 30, 2021, the Company had $475.0 million outstanding under a bank credit facility with a $1.4 billion committed borrowing base which is re-determined on a semi-annual basis and upon the occurrence of certain other events and matures on July 16, 2024. 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 LIBOR plus 2.25% to 3.25% or a base rate plus 1.25% to 2.25%, 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 4.0 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 June 30, 2021.

On March 4, 2021, the Company issued $1.25 billion principal amount of its 6.75% senior notes due 2029 ("the 2029 Notes") in a private placement and received net proceeds after offering costs of $1.24 billion, which were used to repurchase a portion of the Company's 7.5% senior notes due 2025 and 9.75% senior notes due 2026 (the "2026 Notes") pursuant to a tender offer. The 2029 Notes mature on March 1, 2029 and accrue interest at a rate of 6.75% per annum, payable semi-annually on March 1 and September 1 of each year.

Pursuant to the tender offer, Comstock repurchased $375.0 million principal amount of its 7.5% senior notes due 2025 and $777.1 million principal amount of the 2026 Notes for an aggregate amount of $1.26 billion, which included premiums paid over face value of $97.9 million, accrued interest of $12.5 million and $1.1 million of costs related to the tender offer.

On June 28, 2021, the Company issued $965.0 million principal amount of its 5.875% senior notes due 2030 (the "2030 Notes") in a private placement and received net proceeds after offering costs of $949.5 million, which were used along with cash on hand to redeem all outstanding 2026 Notes. The 2030 Notes mature on January 15, 2030 and accrue interest at a rate of 5.875% per annum, payable semi-annually on January 15 and July 15 of each year.

On June 29, 2021, Comstock completed the redemption of all outstanding 2026 Notes for an aggregate amount of $978.6 million, which included premiums paid over face value of $74.0 million and accrued interest of $31.7 million.

As a result of the early retirement of the senior notes repurchased in the tender offer and the redemption of the 2026 Notes, the Company recognized a loss of $114.1 million and $352.6 million on early retirement of debt for the three months and six months ended June 30, 2021, respectively.

(3) PREFERRED STOCK

In connection with the acquisition of Covey Park Energy LLC, the Company issued 210,000 shares of Series A Convertible Preferred Stock with a face value of $210.0 million and a fair value of $200.0 million as part of the consideration for the acquisition and sold 175,000 shares of Series B Convertible Preferred Stock for $175.0 million to its majority stockholder. On May 19, 2020, the Company redeemed the 210,000 outstanding shares of the Series A Convertible Preferred Stock for an aggregate redemption price of $210.0 million plus accrued and unpaid dividends of approximately $2.9 million. The holder of the Series B Convertible Preferred Stock is entitled to receive quarterly dividends at a rate of 10% per annum, which are paid in arrears. The holder of the Series B Convertible Preferred Stock may convert any or all shares of such preferred stock into shares of the Company's common stock at $4.00 per share, subject to adjustment pursuant to customary anti-dilution provisions. The Company has the right to redeem the Series B Convertible Preferred Stock at any time at face value plus accrued dividends. The Series B Convertible Preferred Stock is classified as mezzanine equity based on the majority stockholder's ability to control the terms of conversion to common stock.

(4) COMMITMENTS AND CONTINGENCIES

In April 2021, the Company entered into a well stimulation agreement that extends to 2024 for exclusive use of a natural gas powered pressure pumping fleet. The minimum commitment under this contract is $19.2 million per year from 2022 through 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 June 30, 2021 or 2020.

(5) RELATED PARTY TRANSACTIONS

Comstock operates oil and gas properties held by a partnership owned by its majority stockholder. The Company charges the partnership for the costs incurred to drill, complete and produce the wells, as well as drilling and operating overhead fees that are charged other interest owners. Comstock also provides natural gas marketing services to the partnership, 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 $399 thousand and $810 thousand for the three and six months ended June 30, 2021, and $55 thousand and $379 thousand for the three and six months ended June 30, 2020, respectively, for drilling, operating and marketing services provided to the partnership.

In connection with our operation of the wells, the Company had a $17.8 million receivable from the partnership at June 30, 2021, which was collected in full in August 2021. The Company also had a $10.1 million receivable for the fair market value of oil and natural gas price hedging contracts that were entered into with the partnership.

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, 2020.

Results of Operations


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
Net Production Data:	(In thousands except per unit amounts)
Natural gas (MMcf)	124,083		116,477		237,376		239,263
Oil (MBbls)	362		360		688		814
Natural gas equivalent (MMcfe)	126,260		118,631		241,506		244,144
Revenues:
Natural gas sales	$	321,520	$	172,362	$	645,480	$	379,601
Oil sales	22,173		7,173		38,698		25,812
Total oil and gas sales	$	343,693	$	179,535	$	684,178	$	405,413
Expenses:
Production and ad valorem taxes	$	10,141	$	9,569	$	19,793	$	17,970
Gathering and transportation	$	31,736	$	26,590	$	61,194	$	55,001
Lease operating	$	26,011	$	27,820	$	50,574	$	53,698
Depreciation, depletion and amortization	$	121,446	$	103,347	$	230,574	$	213,772
Exploration	$	—	$	—	$	—	$	27
Average Sales Price:
Natural gas (per Mcf)	$	2.59	$	1.48	$	2.72	$	1.59
Oil (per Bbl)	$	61.25	$	19.97	$	56.25	$	31.72
Average equivalent (Mcfe)	$	2.72	$	1.51	$	2.83	$	1.66
Expenses ($ per Mcfe):
Production and ad valorem taxes	$	0.08	$	0.08	$	0.08	$	0.07
Gathering and transportation	$	0.25	$	0.22	$	0.25	$	0.23
Lease operating	$	0.21	$	0.24	$	0.21	$	0.22
Depreciation, depletion and amortization	$	0.96	$	0.87	$	0.95	$	0.88

Revenues –

Oil and natural gas sales of $343.7 million increased by $164.2 million (91%) in the second quarter of 2021 as compared to $179.5 million for the second quarter of 2020. The increase was primarily due to higher prices received for our oil and natural gas production as well as increased natural gas production. Our natural gas production for the second quarter of 2021 was 124.1 billion cubic feet ("Bcf") (1.4 Bcf per day), which was sold at an average price of $2.59 per Mcf as compared to 116.5 Bcf (1.3 Bcf per day) sold at an average price of $1.48 per Mcf in the second quarter of 2020. Oil production of 362 MBbls (3,978 Bbls per day) was sold at an average price of $61.25 per Bbl in the second quarter of 2021 as compared to 360 MBbls (3,956 Bbls per day) sold at an average price of $19.97 per Bbl in the second quarter of 2020.

Oil and natural gas sales of $684.2 million increased by $278.8 million (69%) for the six months ended June 30, 2021 compared to $405.4 million for the six months ended June 30, 2020, which was primarily due to higher prices received for our oil and natural gas production. Our natural gas production for the first six months of 2021 was 237.4 Bcf (1.3 Bcf per day) was sold at an average price of $2.72 per Mcf as compared to 239.3 Bcf (1.3 Bcf per day) sold at an average price of $1.59 per Mcf in the first six months of 2020. Oil production of 688 Mbbls (3,801 Bbls per day) was sold at an average price of $56.25 per Bbl in the first six months of 2021 as compared to 814 Mbbls (4,473 Bbls per day) sold at an average price of $31.72 per Bbl in the first six months of 2020.

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


	Three Months Ended Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
Average Realized Natural Gas Price:
Natural gas, per Mcf	$	2.59	$	1.48	$	2.72	$	1.59
Cash settlements on derivative financial instruments, per Mcf	(0.13)		$	0.40	$	(0.10)	$	0.37
Price per Mcf, including cash settlements on derivative financial instruments	$	2.46	$	1.88	$	2.62	$	1.96
Average Realized Oil Price:
Oil, per Bbl	$	61.25	$	19.97	$	56.25	$	31.72
Cash settlements on derivative financial instruments, per Bbl	(5.43)		17.92		(4.19)		10.87
Price per Bbl, including cash settlements on derivative financial instruments	$	55.82	$	37.89	$	52.06	$	42.59

Costs and Expenses –

Our production and ad valorem taxes increased $0.6 million (6%) to $10.1 million for the second quarter of 2021 from $9.6 million in the second quarter of 2020. Production and ad valorem taxes increased $1.8 million (10%) to $19.8 million for the first six months of 2021 from $18.0 million in the first six months of 2020. The increase was primarily due to the higher oil and natural gas sales in 2021.

Gathering and transportation costs for the second quarter of 2021 increased $5.1 million (19%) to $31.7 million as compared to $26.6 million in the second quarter of 2020. Gathering and transportation costs for the first six months of 2021 increased $6.2 million (11%) to $61.2 million as compared to $55.0 million for the first six months of 2020. The increase is due primarily to higher average rates in 2021 in addition to the higher production in the second quarter of 2021.

Our lease operating expense of $26.0 million ($0.21 per Mcfe) for the second quarter of 2021 decreased $1.8 million (7%) from lease operating expense of $27.8 million ($0.24 per Mcfe) for the second quarter of 2020. Our lease operating expense of $50.6 million ($0.21 per Mcfe) for the first six months of 2021 decreased $3.1 million (6%) from lease operating expense of $53.7 million ($0.22 per Mcfe) for the first six months of 2020. The decrease in average per unit cost is related to the growth in our lower cost natural gas production where much of the operating costs are fixed in nature.

Depreciation, depletion and amortization ("DD&A") increased $18.1 million (18%) to $121.4 million in the second quarter of 2021 from $103.3 million in the second quarter of 2020. Our DD&A per equivalent Mcf produced increased $0.09 (10%) to $0.96 per Mcfe for the three months ended June 30, 2021 from $0.87 per Mcfe for the three months ended June 30, 2020. DD&A increased $16.8 million (8%) to $230.6 million in the first six months of 2021 from $213.8 million in the first six months of 2020. Our DD&A per equivalent Mcf produced increased $0.07 (8%) to $0.95 per Mcfe for the first six months of 2021 from $0.88 per Mcfe for the first six months of 2020.

General and administrative expenses, which are reported net of overhead reimbursements, decreased to $7.9 million for the second quarter of 2021 from $8.3 million in the second quarter of 2020. General and administrative expenses decreased to $15.9 million for the first six months of 2021 from $17.0 million in the first six months of 2020. The decreases were primarily related to increased overhead reimbursements in 2021.

We use derivative financial instruments as part of our price risk management program to protect our capital investments. During the three months ended June 30, 2021, we had net losses on derivative financial instruments of $224.0 million, as compared to net losses on derivative financial instruments of $12.3 million during the three months ended June 30, 2020. Realized net losses from our oil and natural gas price risk management program were $18.8 million for the three months ended June 30, 2021 as compared to realized net gains of $53.2 million for the three months ended June 30, 2021. Realized losses from our interest rate risk management program were $292 thousand for the three months ended June 30, 2021 as compared to net gains of $63 thousand for the three months ended June 30, 2020. During the six months ended June 30, 2021, we had net losses on derivative financial instruments of $245.7 million, as compared to net gains on derivative financial instruments of $49.6 million during the the first six months of 2020. Realized net losses from our oil and natural gas price risk management program were $27.3 million and net gains of $98.6 million for the six months ended June 30, 2021 and 2020, respectively. Realized losses from our interest rate risk management program were $561 thousand for the six months ended June 30, 2021 as compared to net gains of $63 thousand for the six months ended June 30, 2020.

Interest expense was $56.9 million and $52.1 million for the three months ended June 30, 2021 and 2020, respectively. Interest expense was $120.7 million and $104.9 million for the six months ended June 30, 2021 and 2020, respectively. The increase in interest expense is due primarily to the issuance of additional 9.75% senior notes in 2020.

Income taxes for the three months ended June 30, 2021 and 2020 were a benefit of $68.2 million and $11.4 million, respectively. Income taxes for the six months ended June 30, 2021 and 2020 were a benefit of $98.1 million and $0.1 million, respectively. The benefit for income taxes for the three months and six months ended June 30, 2021 reflect an effective tax rate of 27.5% and 23.8%, respectively. The benefit for income taxes for the three months and six months ended June 30, 2020 reflect an effective tax rate of 18.7% and 0.7%, respectively. The difference between the federal statutory rate of 21% and our effective rate is primarily due to the impact of state income taxes, including changes to Louisiana state tax law enacted in the second quarter of 2021.

We reported net loss available to common stockholders of $184.1 million or $0.80 per share, for the three months ended June 30, 2021 due primarily to the $224.0 million in losses from derivative financial instruments and the $114.1 million loss on early retirement of our 9.75% senior notes. Income from operations was $146.5 million and we had interest expense of $56.9 million and $4.4 million in preferred stock dividends. We reported net loss available to common stockholders of $60.0 million or $0.29 per share for the three months ended June 30, 2020. In the first six months of 2021, we reported net loss available to common stockholders of $322.5 million or $1.39 per share. Our net loss during this period includes income from operations of $306.2 million, which were offset by losses on derivative financial instruments of $245.7 million, interest expense of $120.7 million and $352.6 million in losses on early retirement of debt. We reported net loss of $30.0 million or $0.15 per share for the six months ended June 30, 2020.

Liquidity and Capital Resources

Funding for our activities has historically been provided by our operating cash flow, debt or equity financings or proceeds from asset sales. For the six months ended June 30, 2021, we generated $385.6 million in cash flow from operating activities as compared to $266.1 million in cash flow from operating activities for the six months ended June 30, 2020.

The following table summarizes our capital expenditure activity:


	Six Months Ended June 30,
	2021		2020
	(In thousands)

Exploration and development:
Exploratory leasehold costs	$	13,401	$	—
Development leasehold costs	6,061		6,336
Development drilling and completion costs	312,887		183,480
Other development costs	8,931		15,418
Total capital expenditures	$	341,280	$	205,234

We drilled 50 (34.4 net) wells and completed 35 (24.5 net) Haynesville shale wells during the first six months of 2021. We expect to spend an additional $200 million to $240 million in the remaining six months of 2021 to drill 25 (21.7 net) additional wells, to complete 29 (24.3 net) wells and for other development activity. We expect to fund our future development and exploration activities with future operating cash flow. The timing of most of our future capital expenditures is discretionary because we have no 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 additional equity or debt financings. 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 2021 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, oil and natural gas 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.

On March 4, 2021, we issued $1.25 billion principal amount of our 6.75% senior notes due in 2029 (the "2029 Notes") in a private placement and received net proceeds after offering costs of $1.24 billion, which were used to repurchase a portion of our 7.5% senior notes due in 2025 (the "2025 Notes") and 9.75% senior notes due in 2026 (the "2026 Notes") pursuant to a tender offer. The 2029 Notes mature on March 1, 2029 and accrue interest at a rate of 6.75% per annum, payable semi-annually on March 1 and September 1 of each year.

Pursuant to the tender offer, we repurchased $375.0 million principal amount of the 2025 Notes and $777.1 million principal amount of the 2026 Notes for an aggregate amount of $1.26 billion, which included premiums paid over face value of $97.9 million, accrued interest of $12.5 million and $1.1 million of costs related to the tender offer.

On June 28, 2021, we issued $965.0 million principal amount of our 5.875% senior notes due in 2030 (the "2030 Notes") in a private placement and received net proceeds after offering costs of $949.5 million, which were used along with cash on hand to redeem all outstanding 2026 Notes. The 2030 Notes mature on January 15, 2030 and accrue interest at a rate of 5.875% per annum, payable semi-annually on January 15 and July 15 of each year.

On June 29, 2021, we completed the redemption of all outstanding 2026 Notes for $978.6 million, which included premiums paid over face value of $74.0 million and accrued interest of $31.7 million. As a result of the early retirement of the senior notes repurchased in the tender offer and the redemption of the 2026 Notes, we recognized a loss of $114.1 million and $352.6 million on early retirement of debt for the three months and six months ended June 30, 2021, respectively.

At June 30, 2021, we had $475.0 million outstanding under our bank credit facility with a $1.4 billion committed borrowing base, which is re-determined on a semi-annual basis and upon the occurrence of certain other events, and matures on July 16, 2024. The borrowing base was redetermined at $1.4 billion on April 16, 2021. 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 LIBOR plus 2.25% to 3.25% or a base rate plus 1.25% to 2.25%, 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 4.0 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 June 30, 2021.

In April 2021, we entered into a well stimulation agreement that extends to 2024 for exclusive use of a natural gas powered pressure pumping fleet. The minimum commitment under this contract is $19.2 million per year from 2022 through 2024.

Income Taxes

At June 30, 2021, we had $946.1 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 $117 million.

Effective June 30, 2021, Louisiana state tax law was amended to provide that all NOL deductions claimed on any corporate income tax return filed on or after January 1, 2022 for NOLs relating to loss years on or after January 1, 2001 may be carried forward indefinitely until such losses are fully recovered, subject to other limitations.

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 $800.5 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 oil and natural gas prices include the level of global demand for oil, the foreign supply of oil and natural gas, 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 oil and natural gas 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 oil and natural gas 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 June 30, 2021, we had natural gas price swap agreements which hedge approximately 180.1 Bcf of our 2021 and 2022 natural gas production at an average price of $2.62 per MMBtu and natural gas swaption contracts where the counterparty has the right to exercise a call option to enter into a price swap with the Company on 43.8 Bcf of our 2022 natural gas production at an average price of $2.51 per MMBtu. We also had natural gas collars to hedge approximately 188.2 Bcf of our 2021 and 2022 natural gas production with an average floor price of $2.50 per MMBtu and an average ceiling price of $3.29 per MMBtu. We also have oil collars to hedge 276,000 Bbls with an average floor price of $41.67 per Bbl and an average ceiling price of $51.67 per Bbl. None of our derivative contracts have margin requirements or collateral provisions that could require funding prior to the scheduled cash settlement date. The change in the fair value of our natural gas swaps that would result from a 10% change in commodities prices at June 30, 2021 would be $49.2 million. Such a change in fair value could be a gain or a loss depending on whether prices increase or decrease. Based on our oil and natural gas production for the three months ended June 30, 2021 and our outstanding natural gas price swap agreements, a $0.10 change in the price per Mcf of natural gas would have changed our cash flow by approximately $12.7 million. Our natural gas collars, which cover the period July 1, 2021 through December 31, 2021, will result in natural gas prices on 74.2 Bcf of our future production to be subject to a floor price of $2.47 per MMBtu and an average ceiling price of $3.04 per MMBtu. Our crude oil price collars which cover the period July 1, 2021 through December 31, 2021 will result in oil prices on 276,000 Bbls of our future oil production to be subject to a floor price of $41.67 per Bbl and an average ceiling price of $51.67 per Bbl. These collars may increase or decrease our cash flow depending upon whether future prices are below the floor or above the ceiling prices.

Interest Rates

At June 30, 2021, we had approximately $2.5 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%, $1.25 billion of our long-term debt bear interest at a fixed rate of 6.75% and $244.4 million of our long-term debt bear interest at a fixed rate of 7.50% (the "2025 Notes"). The fair market value of the 2030 Notes, 2029 Notes and 2025 Notes as of June 30, 2021 was $984.3 million, $1,328.1 million and $253.6 million, respectively, based on the market price of approximately 102%, 106% and 104% of the face amount of such debt. At June 30, 2021, we had $475.0 million outstanding under our bank credit facility, which is subject to variable rates of interest that are tied to LIBOR or the corporate base rate, at our option. We have interest rate swap agreements that fix LIBOR at 0.33% for $500.0 million of our floating rate long-term debt. 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 June 30, 2021, 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 June 30, 2021 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 June 30, 2021 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: August 5, 2021			/s/ M. JAY ALLISON
			M. Jay Allison, Chairman and Chief Executive Officer
			(Principal Executive Officer)

Date: August 5, 2021			/s/ ROLAND O. BURNS
			Roland O. Burns, President, Chief Financial Officer and Secretary
			(Principal Financial and Accounting Officer)