false2022Q2000002319412-3100000231942022-01-012022-06-3000000231942022-08-03xbrli:shares00000231942022-06-30iso4217:USD00000231942021-12-31iso4217:USDxbrli:shares0000023194us-gaap:NaturalGasProductionMember2022-04-012022-06-300000023194us-gaap:NaturalGasProductionMember2021-04-012021-06-300000023194us-gaap:NaturalGasProductionMember2022-01-012022-06-300000023194us-gaap:NaturalGasProductionMember2021-01-012021-06-300000023194us-gaap:OilAndCondensateMember2022-04-012022-06-300000023194us-gaap:OilAndCondensateMember2021-04-012021-06-300000023194us-gaap:OilAndCondensateMember2022-01-012022-06-300000023194us-gaap:OilAndCondensateMember2021-01-012021-06-300000023194crk:NaturalGasAndOilSalesMember2022-04-012022-06-300000023194crk:NaturalGasAndOilSalesMember2021-04-012021-06-300000023194crk:NaturalGasAndOilSalesMember2022-01-012022-06-300000023194crk:NaturalGasAndOilSalesMember2021-01-012021-06-300000023194crk:GasServicesMember2022-04-012022-06-300000023194crk:GasServicesMember2021-04-012021-06-300000023194crk:GasServicesMember2022-01-012022-06-300000023194crk:GasServicesMember2021-01-012021-06-3000000231942022-04-012022-06-3000000231942021-04-012021-06-3000000231942021-01-012021-06-300000023194us-gaap:CommonStockMember2020-12-310000023194us-gaap:AdditionalPaidInCapitalMember2020-12-310000023194us-gaap:RetainedEarningsMember2020-12-3100000231942020-12-310000023194us-gaap:CommonStockMember2021-01-012021-03-310000023194us-gaap:AdditionalPaidInCapitalMember2021-01-012021-03-3100000231942021-01-012021-03-310000023194us-gaap:RetainedEarningsMember2021-01-012021-03-310000023194us-gaap:CommonStockMember2021-03-310000023194us-gaap:AdditionalPaidInCapitalMember2021-03-310000023194us-gaap:RetainedEarningsMember2021-03-3100000231942021-03-310000023194us-gaap:CommonStockMember2021-04-012021-06-300000023194us-gaap:AdditionalPaidInCapitalMember2021-04-012021-06-300000023194us-gaap:RetainedEarningsMember2021-04-012021-06-300000023194us-gaap:CommonStockMember2021-06-300000023194us-gaap:AdditionalPaidInCapitalMember2021-06-300000023194us-gaap:RetainedEarningsMember2021-06-3000000231942021-06-300000023194us-gaap:CommonStockMember2021-12-310000023194us-gaap:AdditionalPaidInCapitalMember2021-12-310000023194us-gaap:RetainedEarningsMember2021-12-310000023194us-gaap:CommonStockMember2022-01-012022-03-310000023194us-gaap:AdditionalPaidInCapitalMember2022-01-012022-03-3100000231942022-01-012022-03-310000023194us-gaap:RetainedEarningsMember2022-01-012022-03-310000023194us-gaap:CommonStockMember2022-03-310000023194us-gaap:AdditionalPaidInCapitalMember2022-03-310000023194us-gaap:RetainedEarningsMember2022-03-3100000231942022-03-310000023194us-gaap:CommonStockMember2022-04-012022-06-300000023194us-gaap:AdditionalPaidInCapitalMember2022-04-012022-06-300000023194us-gaap:RetainedEarningsMember2022-04-012022-06-300000023194us-gaap:CommonStockMember2022-06-300000023194us-gaap:AdditionalPaidInCapitalMember2022-06-300000023194us-gaap:RetainedEarningsMember2022-06-3000000231942022-04-010000023194us-gaap:GeneralAndAdministrativeExpenseMember2022-04-012022-06-300000023194us-gaap:GeneralAndAdministrativeExpenseMember2021-04-012021-06-300000023194us-gaap:GeneralAndAdministrativeExpenseMember2022-01-012022-06-300000023194us-gaap:GeneralAndAdministrativeExpenseMember2021-01-012021-06-300000023194crk:LeaseOperatingExpenseMember2022-04-012022-06-300000023194crk:LeaseOperatingExpenseMember2021-04-012021-06-300000023194crk:LeaseOperatingExpenseMember2022-01-012022-06-300000023194crk:LeaseOperatingExpenseMember2021-01-012021-06-300000023194crk:OperatingLeaseCostsIncludedInProvedOilAndGasPropertiesMember2022-04-012022-06-300000023194crk:OperatingLeaseCostsIncludedInProvedOilAndGasPropertiesMember2021-04-012021-06-300000023194crk:OperatingLeaseCostsIncludedInProvedOilAndGasPropertiesMember2022-01-012022-06-300000023194crk:OperatingLeaseCostsIncludedInProvedOilAndGasPropertiesMember2021-01-012021-06-300000023194crk:VariableLeaseCostsIncludedInProvedOilAndGasPropertiesMember2022-04-012022-06-300000023194crk:VariableLeaseCostsIncludedInProvedOilAndGasPropertiesMember2021-04-012021-06-300000023194crk:VariableLeaseCostsIncludedInProvedOilAndGasPropertiesMember2022-01-012022-06-300000023194crk:VariableLeaseCostsIncludedInProvedOilAndGasPropertiesMember2021-01-012021-06-300000023194crk:ShortTermDrillingRigCostsIncludedInProvedOilAndGasPropertiesMember2022-04-012022-06-300000023194crk:ShortTermDrillingRigCostsIncludedInProvedOilAndGasPropertiesMember2021-04-012021-06-300000023194crk:ShortTermDrillingRigCostsIncludedInProvedOilAndGasPropertiesMember2022-01-012022-06-300000023194crk:ShortTermDrillingRigCostsIncludedInProvedOilAndGasPropertiesMember2021-01-012021-06-30xbrli:pure0000023194crk:SwapContractsForYearOneMembercrk:BasisSwapNaturalGasSwapContractsMember2022-01-012022-06-30utr:MMBTU0000023194crk:BasisSwapNaturalGasSwapContractsMembercrk:SwapContractsForYearTwoMember2022-01-012022-06-300000023194crk:BasisSwapNaturalGasSwapContractsMember2022-01-012022-06-300000023194crk:SwapContractsForYearOneMembercrk:BasisSwapNaturalGasSwapContractsMember2022-06-30iso4217:USDutr:MMBTU0000023194crk:BasisSwapNaturalGasSwapContractsMember2022-06-300000023194crk:BasisSwapNaturalGasCollarContractsTwoMembercrk:CollarContractOneForYearOneMember2022-01-012022-06-300000023194crk:CollarContractOneForYearTwoMembercrk:BasisSwapNaturalGasCollarContractsTwoMember2022-01-012022-06-300000023194crk:BasisSwapNaturalGasCollarContractsTwoMember2022-01-012022-06-300000023194crk:BasisSwapNaturalGasCollarContractsTwoMembercrk:CollarContractOneForYearOneMember2022-06-300000023194crk:CollarContractOneForYearTwoMembercrk:BasisSwapNaturalGasCollarContractsTwoMember2022-06-300000023194crk:BasisSwapNaturalGasCollarContractsTwoMember2022-06-300000023194crk:BasisSwapContractsForYearOneMembercrk:BasisSwapNaturalGasContractsThreeMember2022-01-012022-06-300000023194crk:BasisSwapContractsForYearTwoMembercrk:BasisSwapNaturalGasContractsThreeMember2022-01-012022-06-300000023194crk:BasisSwapNaturalGasContractsThreeMember2022-01-012022-06-300000023194crk:BasisSwapContractsForYearOneMembercrk:BasisSwapNaturalGasContractsThreeMember2022-06-300000023194crk:BasisSwapNaturalGasContractsThreeMember2022-06-300000023194crk:BasisSwapNaturalGasPriceDerivativesMember2022-06-300000023194crk:BasisSwapNaturalGasPriceDerivativesMember2021-12-310000023194crk:OilPriceDerivativesMember2022-06-300000023194crk:OilPriceDerivativesMember2021-12-310000023194crk:NaturalGasPriceDerivativesMember2022-04-012022-06-300000023194crk:NaturalGasPriceDerivativesMember2021-04-012021-06-300000023194crk:NaturalGasPriceDerivativesMember2022-01-012022-06-300000023194crk:NaturalGasPriceDerivativesMember2021-01-012021-06-300000023194crk:OilPriceDerivativesMember2022-04-012022-06-300000023194crk:OilPriceDerivativesMember2021-04-012021-06-300000023194crk:OilPriceDerivativesMember2022-01-012022-06-300000023194crk:OilPriceDerivativesMember2021-01-012021-06-300000023194crk:InterestRateDerivativesMember2022-04-012022-06-300000023194crk:InterestRateDerivativesMember2021-04-012021-06-300000023194crk:InterestRateDerivativesMember2022-01-012022-06-300000023194crk:InterestRateDerivativesMember2021-01-012021-06-300000023194us-gaap:RestrictedStockMember2022-06-012022-06-300000023194us-gaap:RestrictedStockMember2022-06-300000023194us-gaap:RestrictedStockMember2022-01-012022-06-300000023194us-gaap:PerformanceSharesMember2022-06-012022-06-300000023194us-gaap:PerformanceSharesMember2022-06-300000023194us-gaap:PerformanceSharesMember2022-01-012022-06-30crk:product0000023194crk:FairValueInputsLevel2AndLevel3Member2022-06-300000023194crk:FairValueInputsLevel2AndLevel3Member2021-12-310000023194us-gaap:LineOfCreditMember2022-06-300000023194us-gaap:LineOfCreditMember2021-12-310000023194crk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2021-12-310000023194crk:SeniorNotesSixPointSevenFivePercentDueTwoThousandTwentyNineMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesSixPointSevenFivePercentDueTwoThousandTwentyNineMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesSixPointSevenFivePercentDueTwoThousandTwentyNineMember2021-12-310000023194crk:SeniorNotesFivePointEightSevenFivePercentDueTwoThousandThirtyMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesFivePointEightSevenFivePercentDueTwoThousandThirtyMember2022-06-300000023194us-gaap:FairValueInputsLevel1Membercrk:SeniorNotesFivePointEightSevenFivePercentDueTwoThousandThirtyMember2021-12-310000023194us-gaap:RestrictedStockMember2021-12-310000023194us-gaap:RestrictedStockMember2022-04-012022-06-300000023194us-gaap:RestrictedStockMember2021-04-012021-06-300000023194us-gaap:PerformanceSharesMember2022-04-012022-06-300000023194us-gaap:PerformanceSharesMember2021-04-012021-06-300000023194us-gaap:RestrictedStockMember2021-01-012021-06-300000023194us-gaap:PerformanceSharesMember2021-01-012021-06-300000023194crk:SeriesBConvertiblePreferredStockMember2020-07-162020-07-1600000231942020-07-162020-07-160000023194crk:EastTexasMembercrk:HaynesvilleShaleMember2022-04-30utr:miutr:acre0000023194crk:EastTexasMembercrk:HaynesvilleShaleMember2022-04-012022-04-300000023194srt:MinimumMemberus-gaap:LineOfCreditMemberus-gaap:LondonInterbankOfferedRateLIBORMember2022-01-012022-06-300000023194us-gaap:LineOfCreditMemberus-gaap:LondonInterbankOfferedRateLIBORMembersrt:MaximumMember2022-01-012022-06-300000023194srt:MinimumMemberus-gaap:LineOfCreditMemberus-gaap:BaseRateMember2022-01-012022-06-300000023194us-gaap:LineOfCreditMembersrt:MaximumMemberus-gaap:BaseRateMember2022-01-012022-06-300000023194srt:MinimumMemberus-gaap:LineOfCreditMember2022-01-012022-06-300000023194us-gaap:LineOfCreditMembersrt:MaximumMember2022-01-012022-06-300000023194us-gaap:LineOfCreditMember2022-01-012022-06-300000023194crk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2022-05-310000023194crk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2022-05-012022-05-310000023194crk:SeniorNotesSixPointSevenFivePercentDueTwoThousandTwentyNineMember2022-06-012022-06-300000023194crk:SeniorNotesSevenPointFivePercentDueTwoThousandTwentyFiveMember2022-01-012022-06-300000023194crk:SeniorNotesNinePointSevenFivePercentDueTwoThousandTwentySixMember2022-01-012022-06-300000023194crk:SeniorNotesNinePointSevenFivePercentDueTwoThousandTwentySixMember2021-03-310000023194crk:SeniorNotesSixPointSevenFivePercentDueTwoThousandTwentyNineMember2022-01-012022-06-3000000231942019-07-162019-07-1600000231942020-05-190000023194srt:AffiliatedEntityMember2022-01-012022-06-30iso4217:USDutr:Mcf0000023194crk:PartnershipCostsToDrillAndOperateWellsAndOverheadFeesMembersrt:AffiliatedEntityMember2022-04-012022-06-300000023194crk:PartnershipCostsToDrillAndOperateWellsAndOverheadFeesMembersrt:AffiliatedEntityMember2021-04-012021-06-300000023194crk:PartnershipCostsToDrillAndOperateWellsAndOverheadFeesMembersrt:AffiliatedEntityMember2022-01-012022-06-300000023194crk:PartnershipCostsToDrillAndOperateWellsAndOverheadFeesMembersrt:AffiliatedEntityMember2021-01-012021-06-300000023194srt:AffiliatedEntityMember2022-06-300000023194srt:AffiliatedEntityMember2021-12-31


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, 2022
or
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 3, 2022 was 233,165,068.




COMSTOCK RESOURCES, INC.
QUARTERLY REPORT
For the Quarter Ended June 30, 2022
INDEX






2

















PART I — FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
3



COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS

As of
June 30,
2022
December 31,
2021
(Unaudited)
(In thousands)
ASSETS
Cash and cash equivalents $ 32,272  $ 30,663 
Accounts receivable:
Oil and gas sales
436,379  217,149 
Joint interest operations
27,127  29,755 
From affiliates
8,150  20,834 
Derivative financial instruments 2,086  5,258 
Other current assets 24,797  15,077 
Total current assets
530,811  318,736 
Property and equipment:
Oil and natural gas properties, successful efforts method:
Proved
5,263,298  4,756,394 
Unproved
308,468  302,129 
Other
24,559  6,690 
Accumulated depreciation, depletion and amortization
(1,283,124) (1,058,067)
Net property and equipment
4,313,201  4,007,146 
Goodwill 335,897  335,897 
Operating lease right-of-use assets 108,284  6,450 
$ 5,288,193  $ 4,668,229 
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable $ 454,752  $ 314,569 
Accrued costs 153,763  135,026 
Operating leases 37,561  2,444 
Derivative financial instruments 318,585  181,945 
Total current liabilities
964,661  633,984 
Long-term debt 2,510,253  2,615,235 
Deferred income taxes 267,746  197,417 
Derivative financial instruments —  4,042 
Long-term operating leases 70,797  4,075 
Reserve for future abandonment costs 28,433  25,673 
Other non-current liabilities 24  24 
Total liabilities
3,841,914  3,480,450 
Commitments and contingencies
Mezzanine equity:
Series B Convertible Preferred stock — 5,000,000 shares authorized, 175,000 shares issued and outstanding at June 30, 2022 and December 31, 2021, respectively
175,000  175,000 
Stockholders' equity:
Common stock—$0.50 par, 400,000,000 shares authorized, 233,158,892 and 232,924,646 shares issued and outstanding at June 30, 2022 and December 31, 2021, respectively
116,579  116,462 
Additional paid-in capital
1,101,953  1,100,359 
Accumulated earnings (deficit) 52,747  (204,042)
Total stockholders' equity
1,271,279  1,012,779 
$ 5,288,193  $ 4,668,229 



The accompanying notes are an integral part of these statements.
4



COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)


Three Months Ended
June 30,
Six Months Ended
June 30,
2022 2021 2022 2021
(In thousands, except per share amounts)
Revenues:
Natural gas sales
$ 858,838  $ 321,520  $ 1,381,795  $ 645,480 
Oil sales
2,504  22,173  4,388  38,698 
Total oil and gas sales
861,342  343,693  1,386,183  684,178 
Gas services 84,912  —  129,485  — 
Total revenues 946,254  343,693  1,515,668  684,178 
Operating expenses:
Production and ad valorem taxes
21,729  10,141  35,549  19,793 
Gathering and transportation
36,964  31,736  69,057  61,194 
Lease operating
25,079  26,011  51,265  50,574 
Exploration
2,342  —  3,363  — 
Depreciation, depletion and amortization
119,201  121,446  225,929  230,574 
Gas services 82,778  —  123,453  — 
General and administrative
9,063  7,872  17,286  15,900 
Gain on sale of assets (19) (9) (21) (79)
Total operating expenses
297,137  197,197  525,881  377,956 
Operating income 649,117  146,496  989,787  306,222 
Other income (expenses):
Loss from derivative financial instruments (72,826) (223,958) (510,319) (245,707)
Other income 182  530  450  811 
Interest expense
(44,320) (56,880) (90,811) (120,691)
Loss on early retirement of debt
(46,840) (114,060) (46,840) (352,599)
Total other expenses (163,804) (394,368) (647,520) (718,186)
Income (loss) before income taxes 485,313  (247,872) 342,267  (411,964)
(Provision for) benefit from income taxes (108,422) 68,177  (76,800) 98,144 
Net income (loss) 376,891  (179,695) 265,467  (313,820)
Preferred stock dividends (4,363) (4,363) (8,678) (8,678)
Net income (loss) available to common stockholders $ 372,528  $ (184,058) $ 256,789  $ (322,498)
Net income (loss) per share:
Basic
$ 1.60  $ (0.80) $ 1.10  $ (1.39)
Diluted
$ 1.36  $ (0.80) $ 0.96  $ (1.39)
Weighted average shares outstanding:
Basic
232,045  231,428  232,011  231,403 
Diluted
277,614  231,428  277,485  231,403 








The accompanying notes are an integral part of these statements.
5



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, 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 
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 dividends
—  —  —  (4,315) (4,315)
Balance at March 31, 2022 232,920  $ 116,460  $ 1,101,838  $ (319,781) $ 898,517 
Stock-based compensation
239  119  115  —  234 
Net income —  —  —  376,891  376,891 
Payment of preferred dividends
—  —  —  (4,363) (4,363)
Balance at June 30, 2022 233,159  $ 116,579  $ 1,101,953  $ 52,747  $ 1,271,279 
















The accompanying notes are an integral part of these statements.
6



COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)


Six Months Ended June 30,
2022 2021
(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ 265,467  $ (313,820)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Deferred income taxes
70,329  (101,281)
Gain on sale of assets (21) (79)
Depreciation, depletion and amortization
225,929  230,574 
Loss on derivative financial instruments 510,319  245,707 
Cash settlements of derivative financial instruments
(374,549) (27,813)
Amortization of debt discount and issuance costs
7,098  13,575 
Stock-based compensation
3,076  3,489 
Loss on early retirement of debt
46,840  352,599 
Increase in accounts receivable (203,918) (40,190)
(Increase) decrease in other current assets (9,720) 5,528 
Increase in accounts payable and accrued expenses 145,083  17,294 
Net cash provided by operating activities 685,933  385,583 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures
(515,454) (338,779)
Proceeds from sales of assets
93  211 
Net cash used for investing activities (515,361) (338,568)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on bank credit facility
595,000  180,000 
Repayments of bank credit facility
(480,000) (205,000)
Issuance of Senior Notes —  2,222,500 
Retirement of Senior Notes
(273,920) (2,210,626)
Preferred stock dividends paid
(8,678) (8,678)
Debt and stock issuance costs
—  (35,558)
Income tax withholdings on equity awards
(1,365) (198)
Net cash used for financing activities (168,963) (57,560)
Net increase (decrease) in cash and cash equivalents 1,609  (10,545)
Cash and cash equivalents, beginning of period
30,663  30,272 
Cash and cash equivalents, end of period
$ 32,272  $ 19,727 












The accompanying notes are an integral part of these statements.
7



COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
June 30, 2022
(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, 2022, 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, 2021.
The results of operations for the period through June 30, 2022 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 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
June 30,
Six Months Ended
June 30,
2022 2022
(In thousands)
Beginning capitalized exploratory project costs $ 18,523  $ 6,966 
Additions to exploratory project costs pending the determination of proved reserves 18,840  30,397 
Determined to have found proved reserves (27,592) (27,592)
Ending capitalized exploratory project costs $ 9,771  $ 9,771 
As of June 30, 2022 and December 31, 2021, 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
8



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, 2022 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 $108.3 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. In April 2022, the Company took delivery of 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.

9



Lease costs recognized during the three months and six months ended June 30, 2022 and 2021 were as follows:
Three Months Ended June 30, Six Months Ended June 30,
2022 2021 2022 2021
(In thousands)
Operating lease cost included in general and administrative expense $ 436  $ 435  $ 871  $ 864 
Operating lease cost included in lease operating expense 329  190  599  422 
Operating lease cost included in proved oil and gas properties 6,300  —  6,300  — 
Variable lease cost (completion costs included in proved oil and gas properties) 11,127  —  11,127  — 
Short-term operating lease cost (drilling rig costs included in proved oil and gas properties) 17,105  7,659  28,140  19,243 
$ 35,297  $ 8,284  $ 47,037  $ 20,529 
Cash payments for operating leases associated with right-of-use assets included in cash provided by operating activities were $0.8 million and $0.6 million for the three months ended June 30, 2022 and 2021, respectively, and $1.5 million and $1.3 million for the six months ended June 30, 2022 and 2021, respectively. Cash payments for operating leases associated with right-of-use assets included in cash used for investing activities were $34.5 million and $7.7 million for the three months ended June 30, 2022 and 2021, respectively, and $45.6 million and $19.2 million for the six months ended June 30, 2022 and 2021, respectively.
As of June 30, 2022 and December 31, 2021, the operating leases had a weighted-average term of 2.8 years and 2.7 years, respectively, and the weighted-average discount rate used to determine the present value of future operating lease payments was 3.5% and 2.7%, respectively. As of June 30, 2022, the Company also had expected future payments for contracted drilling services of $22.2 million.
As of June 30, 2022, expected future payments related to contracts that contain operating leases were as follows:
(In thousands)
July 1 to December 31, 2022 $ 20,391 
2023 40,574 
2024 40,208 
2025 12,727 
2026 53 
Thereafter 17 
Total lease payments
113,970 
Imputed interest (5,612)
Total lease liability $ 108,358 
Accrued Costs
Accrued costs at June 30, 2022 and December 31, 2021 consisted of the following:
As of
June 30,
2022
December 31, 2021
(In thousands)
Accrued interest payable $ 54,377  $ 60,305 
Accrued drilling costs 33,808  19,995 
Accrued income and other taxes 28,431  15,655 
Accrued transportation costs 24,542  22,859 
Accrued employee compensation 7,573  12,320 
Accrued lease operating expenses 1,811  2,036 
Other 3,221  1,856 
$ 153,763  $ 135,026 
10



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:
Six Months Ended
June 30,
2022 2021
(In thousands)
Reserve for future abandonment costs at beginning of period $ 25,673  $ 19,290 
New wells placed on production
844  862 
Acquisition of natural gas treating plant 1,211  — 
Liabilities settled and assets disposed of
(29) (6)
Accretion expense
734  602 
Reserve for future abandonment costs at end of period $ 28,433  $ 20,748 
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, except for certain basis swaps, are tied to the Henry Hub-NYMEX price index. 
The Company had the following oil and natural gas price derivative financial instruments at June 30, 2022:
Future Production Period
Six Months Ending December 31, 2022 Year Ending December 31, 2023 Total
Natural Gas Swap Contracts:
Volume (MMBtu) 58,880,000  —  58,880,000 
Average Price per MMBtu $2.68  $2.68 
Natural Gas Collar Contracts:
Volume (MMBtu) 67,160,000  128,925,000  196,085,000 
Average Price per MMBtu:
Average Ceiling $3.91  $9.85  $7.81 
Average Floor $2.62  $2.98  $2.86 
Natural Gas Basis Swap Contracts:
Volume (MMBtu) 5,520,000  (1) —  5,520,000  (1)
Average Price per MMBtu ($0.16) ($0.16)
_____________________________
(1)Contracts fix the differentials between NYMEX Henry Hub and the Columbia Gulf Mainline indices.
The aggregate fair value of the Company's derivative instruments are presented on a gross basis in the accompanying consolidated balance sheets.
11



The classification of derivative financial instruments between assets and liabilities, consists of the following:
As of
Type Consolidated Balance Sheet Location June 30,
2022
December 31, 2021
(In thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives Derivative Financial Instruments  – current $ 2,086  $ 4,528 
Oil price derivatives Derivative Financial Instruments  – current —  730 
$ 2,086  $ 5,258 
Liability Derivative Financial Instruments:
Natural gas price derivatives Derivative Financial Instruments  – current $ 318,585  $ 181,215 
Oil price derivatives Derivative Financial Instruments  – current —  730 
$ 318,585  $ 181,945 
Natural gas price derivatives Derivative Financial Instruments  – long-term $ —  $ 4,042 
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:
Loss on Derivatives
Recognized in Earnings
Three Months Ended
June 30,
Six Months Ended
June 30,
2022 2021 2022 2021
(In thousands)
Natural gas price derivatives $ (72,826) $ (219,845) $ (510,319) $ (238,722)
Oil price derivatives —  (3,989) —  (7,533)
Interest rate derivatives —  (124) —  548 
$ (72,826) $ (223,958) $ (510,319) $ (245,707)
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 $1.6 million and $1.8 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, 2022 and 2021, respectively, and $3.1 million and $3.5 million for the six months ended June 30, 2022 and 2021, respectively.
In June 2022, the Company granted an aggregate of 317,831 shares of restricted stock to its directors and employees. The grants were valued at $16.80 per share. As of June 30, 2022, Comstock had 930,006 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $9.50 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $7.6 million as of June 30, 2022 is expected to be recognized over a period of 2.4 years.
In June 2022, the Company granted an aggregate of 162,511 PSUs to its executive officers at a value of $25.26 per unit. As of June 30, 2022, Comstock had 1,212,421 PSUs outstanding at a weighted average grant date fair value of $10.41 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 2,424,842 shares of common stock. Total unrecognized compensation cost related to these grants of $6.1 million as of June 30, 2022 is expected to be recognized over a period of 2.5 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
12



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, 2022. 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. 
Gas services revenues represent sales of natural gas purchased for resale and fees received for gathering and treating services provided to unaffiliated third parties. The Company recognizes gas services revenues at the time the performance obligations have been fulfilled.
The Company recognized accounts receivable of $436.4 million as of June 30, 2022 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 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 six months ended June 30, 2022 and 2021.
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.
13



The following is an analysis of the consolidated income tax provision (benefit):
Three Months Ended
June 30,
Six Months Ended
June 30,
2022 2021 2022 2021
(In thousands)
Current - Federal $ 5,360  $ —  $ 1,399  $ — 
Current - State 7,969  3,001  5,509  3,137 
Deferred - Federal 71,292  (58,044) 57,868  (92,963)
Deferred - State 23,801  (13,134) 12,024  (8,318)
$ 108,422  $ (68,177) $ 76,800  $ (98,144)
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,
2022 2021 2022 2021
Tax at statutory rate 21.0  % 21.0  % 21.0  % 21.0  %
Tax effect of:
Valuation allowance on deferred tax assets (3.8) 10.9  (4.0) (7.6)
State income taxes, net of federal benefit
5.0  4.1  5.3  1.3 
Nondeductible stock-based compensation
0.1  0.3  0.1  0.1 
Change in Louisiana tax law —  (8.8) —  9.0 
Effective tax rate 22.3  % 27.5  % 22.4  % 23.8  %
  
The Company's federal income tax returns for the years subsequent to December 31, 2017 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, 2018. 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.
14



In 2021, the Company had natural gas swaption agreements that were 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 using Level 3 measurements in the fair value hierarchy:
Six Months Ended
June 30, 2021
(In thousands)
Balance at beginning of year $ (22,588)
Total loss included in earnings (30,262)
Settlements, net 5,402 
Transfers out of Level 3 (6,418)
Balance at end of period $ (53,866)
Fair Values – Reported
The following presents the carrying amounts and the fair values of the Company's financial instruments as of June 30, 2022 and December 31, 2021:
As of
June 30, 2022 December 31, 2021
Carrying Value Fair Value Carrying Value Fair Value
Assets: (In thousands)
Commodity-based derivatives (1)
$ 2,086  $ 2,086  $ 5,258  $ 5,258 
Liabilities:
Commodity-based derivatives (1)
$ 318,585  $ 318,585  $ 185,987  $ 185,987 
Bank credit facility (2)
$ 350,000  $ 350,000  $ 235,000  $ 235,000 
7.5% senior notes due 2025 (3)
$ —  $ —  $ 196,998  $ 248,066 
6.75% senior notes due 2029 (3)
$ 1,230,235  $ 1,089,253  $ 1,256,874  $ 1,337,500 
5.875% senior notes due 2030 (3)
$ 965,000  $ 834,725  $ 965,000  $ 989,125 
_____________________________
(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 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, 2022 and December 31, 2021, 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, 2022 and December 31, 2021, 930,006 and 952,971 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,
2022 2021 2022 2021
(In thousands)
Unvested restricted stock 905  1,091  926  1,063 
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,
15



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,
2022 2021 2022 2021
(In thousands, except per unit amounts)
Weighted average PSUs 1,080  1,192  1,065  1,165 
Weighted average grant date fair value per unit $10.41  $9.21  $10.41  $9.21 
Basic and diluted income (loss) per share for the three months and six months ended June 30, 2022 and 2021 were determined as follows:
Three Months Ended June 30,
2022 2021
Income Shares Per Share Loss Shares Per Share
(In thousands, except per share amounts)
Net income (loss) attributable to common stock $ 372,528  $ (184,058)
Income allocable to unvested restricted shares (1,447) — 
Basic income (loss) attributable to common stock 371,081  232,045  $ 1.60  (184,058) 231,428  $ (0.80)
Effect of Dilutive Securities:
Restricted stock 1,447  680  —  — 
Performance stock units —  1,139  —  — 
Convertible preferred stock 4,363  43,750  —  — 
Diluted income (loss) attributable to common stock $ 376,891  277,614  $ 1.36  $ (184,058) 231,428  $ (0.80)
Six Months Ended June 30,
2022 2021
Income Shares Per Share Loss Shares Per Share
(In thousands, except per share amounts)
Net income (loss) attributable to common stock $ 256,789  $ (322,498)
Income allocable to unvested restricted shares (1,021) — 
Basic income (loss) attributable to common stock 255,768  232,011  $ 1.10  (322,498) 231,403  $ (1.39)
Effect of Dilutive Securities:
Restricted stock 1,021  640  —  — 
Performance stock units —  1,084  —  — 
Convertible preferred Stock 8,678  43,750  —  — 
Diluted income (loss) attributable to common stock $ 265,467  277,485  $ 0.96  $ (322,498) 231,403  $ (1.39)
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.
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.
16



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, 2022 and 2021, respectively, were as follows:
Six Months Ended
June 30,
2022 2021
(In thousands)
Cash payments for:
Interest payments $ 89,641  $ 143,831 
Income tax payments $ 169  $ — 
Non-cash investing activities include:
Increase in accrued capital expenditures $ 13,813  $ 785 
Liabilities assumed in exchange for right-of-use lease assets $ 108,881  $ 4,998 
(2) ACQUISITION
In April 2022, the Company acquired a 145 mile high pressure pipeline and natural gas treating plant from an unaffiliated third party and the undeveloped deep rights on approximately 60,000 net undeveloped acres in East Texas for $35.6 million including transaction costs. $16.8 million of the purchase price was allocated to the pipeline and plant and recorded to other property and equipment. $18.8 million of the purchase price was allocated and recorded to unproved oil and gas properties.
(3) LONG-TERM DEBT
At June 30, 2022, long-term debt was comprised of the following:
(In thousands)
6.75% Senior Notes due 2029:
Principal 1,223,880 
Premium, net of amortization 6,355 
5.875% Senior Notes due 2030:
Principal 965,000 
Bank Credit Facility:
Principal
350,000 
Debt issuance costs, net of amortization (34,982)
$ 2,510,253 
As of June 30, 2022, the Company had $350.0 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. The borrowing base was redetermined on April 15, 2022. 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, 2022.
In May 2022, the Company completed the early redemption of all of its outstanding 7.5% senior notes due in 2025 for an aggregate amount of $258.1 million, which included principal of $244.4 million, premiums paid over face value of $4.5 million and accrued interest of $9.2 million. As a result of the redemption, the Company recognized a loss of $47.8 million on early retirement of debt including the write-off of $43.3 million of unamortized discount resulting from adjusting the senior notes to fair value on the date that they were assumed by the Company.
17




In June 2022, the Company repurchased $26.1 million principal amount of its 6.75% senior notes due in 2029 for $24.9 million. The Company recognized a gain of $1.0 million on early retirement of debt relating to the repurchase.
During the six months ended June 30, 2021, the Company repurchased $375.0 million principal amount of its 7.5% senior notes due in 2025 and $1,650.0 million principal amount of its 9.75% senior notes due 2026 with proceeds from the issuance of $1,250.0 million principal amount of its 6.75% senior notes due in 2029 and $965.0 million principal amount of its 5.875% senior notes due in 2030. 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.
(4) CONVERTIBLE PREFERRED STOCK
The Company has 175,000 shares outstanding of Series B Convertible Preferred Stock, which are held by its majority stockholder. 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.
(5) COMMITMENTS AND CONTINGENCIES
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, 2022 or 2021.
(6) 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 $0.4 million for the three months ended June 30, 2022 and 2021, respectively, and $0.6 million and $0.8 million for the six months ended June 30, 2022 and 2021, 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 $8.2 million and a $20.8 million receivable from the partnerships at June 30, 2022 and December 31, 2021, respectively.

18



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, 2021.
Results of Operations
Three Months Ended
June 30,
Six Months Ended
June 30,
2022 2021 2022 2021
Net Production Data: (In thousands except per unit amounts)
Natural gas (MMcf)
123,950  124,083  238,856  237,376 
Oil (MBbls) 24  362  45  688 
Natural gas equivalent (MMcfe)
124,092  126,260  239,127  241,506 
Revenues:
Natural gas sales
$ 858,838  $ 321,520  $ 1,381,795  $ 645,480 
Oil sales
2,504  22,173  4,388  38,698 
Total oil and gas sales
$ 861,342  $ 343,693  $ 1,386,183  $ 684,178 
Expenses:
Production and ad valorem taxes $ 21,729  $ 10,141  $ 35,549  $ 19,793 
Gathering and transportation
$ 36,964  $ 31,736  $ 69,057  $ 61,194 
Lease operating $ 25,079  $ 26,011  $ 51,265  $ 50,574 
Exploration
$ 2,342  $ —  $ 3,363  $ — 
Average Sales Price:
Natural gas (per Mcf)
$ 6.93  $ 2.59  $ 5.79  $ 2.72 
Oil (per Bbl)
$ 104.33  $ 61.25  $ 97.51  $ 56.25 
Average equivalent (Mcfe)
$ 6.94  $ 2.72  $ 5.80  $ 2.83 
Expenses ($ per Mcfe):
Production and ad valorem taxes $ 0.18  $ 0.08  $ 0.15  $ 0.08 
Gathering and transportation
$ 0.30  $ 0.25  $ 0.29  $ 0.25 
Lease operating $ 0.20  $ 0.21  $ 0.21  $ 0.21 
Revenues –
Oil and natural gas sales of $861.3 million for the second quarter of 2022 increased by $517.6 million (151%) as compared to $343.7 million for the second quarter of 2021. The increase was primarily due to higher prices received for our natural gas production. Our natural gas production for the second quarter of 2022 was 124.0 billion cubic feet ("Bcf") (1.4 Bcf per day), and was sold at an average price of $6.93 per Mcf as compared to 124.1 Bcf (1.4 Bcf per day) sold at an average price of $2.59 per Mcf in the second quarter of 2021. In October 2021, we sold our Bakken shale properties, which accounted for most of our oil production.
Oil and natural gas sales of $1.4 billion for the six months ended June 30, 2022 increased by $702.0 million (103%) as compared to $684.2 million for the six months ended June 30, 2021, which also was primarily due to higher prices received for our natural gas production. Our natural gas production for the first six months of 2022 increased 1% to 238.9 Bcf (1.3 Bcf per day), and was sold at an average price of $5.79 per Mcf as compared to 237.4 Bcf (1.3 Bcf per day) sold at an average price of $2.72 in the first six months of 2021.

19



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 June 30, Six Months Ended June 30,
2022 2021 2022 2021
Average Realized Natural Gas Price:
Natural gas, per Mcf $ 6.93  $ 2.59  $ 5.79  $ 2.72 
Cash settlements on derivative financial instruments, per Mcf (2.08) (0.13) (1.57) (0.10)
Price per Mcf, including cash settlements on derivative financial instruments $ 4.85  $ 2.46  $ 4.22  $ 2.62 
Average Realized Oil Price:
Oil, per Bbl $ 104.33  $ 61.25  $ 97.51  $ 56.25 
Cash settlements on derivative financial instruments, per Bbl —  (5.43) —  (4.19)
Price per Bbl, including cash settlements on derivative financial instruments $ 104.33  $ 55.82  $ 97.51  $ 52.06 
Gas service revenues of $84.9 million and $129.5 million for the three months and six months ended June 30, 2022, respectively, 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.
Costs and Expenses –
Our production and ad valorem taxes increased $11.6 million (114%) to $21.7 million for the second quarter of 2022 from $10.1 million in the second quarter of 2021. Production and ad valorem taxes increased $15.8 million (80%) to $35.5 million for the first six months of 2022 from $19.8 million in the first six months of 2021. The increase was primarily related to higher natural gas sales in 2022.
Gathering and transportation costs for the second quarter of 2022 increased $5.2 million (16%) to $37.0 million as compared to $31.7 million in the second quarter of 2021. Gathering and transportation costs for the first six months of 2022 increased $7.9 million (13%) to $69.1 million as compared to $61.2 million for the first six months of 2021. The increase is due to additional transportation costs related to our operated natural gas production.
Our lease operating expense of $25.1 million ($0.20 per Mcfe) for the second quarter of 2022 decreased $0.9 million (4%) from lease operating expense of $26.0 million ($0.21 per Mcfe) for the second quarter of 2021. Lease operating expense of $51.3 million ($0.21 per Mcfe) for the first six months of 2022 increased $0.7 million (1%) from lease operating expense of $50.6 million ($0.21 per Mcfe) for the first six months of 2021.
Gas service expenses were $82.8 million and $123.5 million for the three months and six months ended June 30, 2022 and 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") decreased $2.2 million (2%) to $119.2 million in the second quarter of 2022 from $121.4 million in the second quarter of 2021. Our DD&A per equivalent Mcf produced was $0.96 per Mcfe for both the quarter ended June 30, 2022 and 2021. DD&A decreased $4.6 million (2%) to $225.9 million in the first six months of 2022 from $230.6 million in the first six months of 2021. Our DD&A per equivalent Mcf produced decreased $0.01 to $0.94 per Mcfe for the first six months of 2022 from $0.95 per Mcfe for the first six months of 2021.
General and administrative expenses, which are reported net of overhead reimbursements, increased to $9.1 million for the second quarter of 2022 as compared to $7.9 million in the second quarter of 2021. General and administrative expenses increased to $17.3 million for the first six months of 2022 from $15.9 million in the first six months of 2021. The increases were primarily related to higher compensation expense.
We use derivative financial instruments as part of our price risk management program to protect our capital investments. During the quarter ended June 30, 2022, we had losses related to our derivative financial instruments of $72.8 million, as compared to net losses on derivative financial instruments of $224.0 million during the quarter ended June 30, 2021. Realized net losses from our oil and natural gas price risk management program were $257.4 million for the quarter ended June 30, 2022 as compared to realized net losses of $18.8 million for the quarter ended June 30, 2021. Net losses on derivative financial instruments were $510.3 million for the first six months of 2022 as compared to net losses of $245.7 million for the first six months of 2021. Realized net losses from our oil and natural gas price risk management program were $374.5 million for the first six months of 2022 as compared to realized net losses of $27.3 million for the first six months of 2021.
20



Interest expense was $44.3 million and $56.9 million for the quarters ended June 30, 2022 and 2021, respectively, and $90.8 million and $120.7 million for the six months ended June 30, 2022 and 2021, respectively. The decrease in interest expense is due primarily to the refinancing of our senior notes in 2021 and the early retirements of senior notes in May and June 2022.
Loss on extinguishment of debt was $46.8 million and $114.1 million for the quarter ended June 30, 2022 and 2021, respectively, and $46.8 million and $352.6 million for the six months ended June 30, 2022 and 2021, respectively. In May and June 2022, we retired $244.4 million and $26.1 million, respectively, principal amount of our 7.5% senior notes due in 2025 and 6.75% senior notes due in 2029. In March and June 2021, we redeemed all of our outstanding 9.75% senior notes due in 2026 and $375.0 million principal amount of our 7.5% senior notes due in 2025.
Income taxes for the quarter ended June 30, 2022 and 2021 were an expense of $108.4 million and a benefit of $68.2 million, respectively. Income taxes for the six months ended June 30, 2022 and 2021 were an expense of $76.8 million and a benefit of $98.1 million, respectively. Income tax expense for the three months and six months ended June 30, 2022 reflect an effective tax rate of 22.3% and 22.4%, respectively. The income tax benefit for the three months and six months ended June 30, 2021 reflect an effective tax rate of 27.5% and 23.8%, respectively. The difference between the federal statutory tax rate of 21% and our effective rate is primarily attributable to revisions to the estimated future utilization of federal and state net operating loss carryforwards ("NOL") and the impact of state income taxes.
We reported net income available to common stockholders of $372.5 million or $1.36 per diluted share, for the quarter ended June 30, 2022 which included a $72.8 million net loss from derivative financial instruments and a $46.8 million loss on early retirement of debt. Income from operations for the second quarter of 2022 was $649.1 million and we had interest expense of $44.3 million and $4.4 million in preferred stock dividends. 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. In the first six months of 2022, we reported net income available to common stockholders of $256.8 million or $0.96 per diluted share, which included a $510.3 million net loss from derivative financial instruments and a $46.8 million loss on early retirement of debt. Income from operations for the first six months of 2022 was $989.8 million and we had interest expense of $90.8 million and $8.7 million in preferred stock dividends. We reported net loss available to common stockholders of $322.5 million or $1.39 per share for the six months ended June 30, 2021.
Cash Flows, Liquidity and Capital Resources
Cash Flows
The following table summarizes sources and uses of cash and cash equivalents:
Six Months Ended
June 30,
2022 2021
(In thousands)
Sources of cash and cash equivalents:
Operating activities $ 685,933  $ 385,583 
Issuance of new senior notes, net of costs —  2,187,098 
Borrowings on bank credit facility, net of repayments 115,000  — 
Proceeds from asset sales 93  211 
Total $ 801,026  $ 2,572,892 
Uses of cash and cash equivalents:
Capital expenditures $ 515,454  $ 338,779 
Retirement of senior notes 273,920  2,210,626 
Repayments of bank credit facility, net of borrowings —  25,000 
Preferred stock dividends 8,678  8,678 
Other 1,365  354 
Total $ 799,417  $ 2,583,437 

21



Cash flows from operating activities. Net cash provided by our operating activities increased $300.4 million (78%) to $685.9 million in the first six months of 2022 from $385.6 million in the same period in 2021. The increase is primarily due to higher realized natural gas prices in 2022.
Issuance of new senior notes and retirement of senior notes. In May 2022, we retired all of our outstanding 7.5% senior notes due in 2025 for $248.9 million, which included premiums paid over face value of $4.5 million. During June 2022, we retired $26.1 million principal amount of our 6.75% senior notes for $24.9 million.
In 2021, we issued $1.25 billion principal amount of 6.75% senior notes due in 2029 and $965.0 million principal amount of 5.875% senior notes due in 2030. The proceeds from the note offerings were used to redeem $2,025.0 million principal amount of outstanding senior notes for $2,198.1 million, including premiums paid over face value and costs related to a tender offer.
Capital expenditures. The increase in capital expenditures of $176.7 million is primarily due to our higher drilling and completion activity in 2022 and the acquisition of undeveloped Haynesville shale acreage and a high pressure natural gas pipeline and treating plant from an unaffiliated third party.
The following table summarizes our capital expenditure activity:
Six Months Ended
June 30,
2022 2021
(In thousands)
Acquisitions:
Proved property $ 205  $ — 
Unproved property 25,182  13,401 
Exploration and development:
Development leasehold costs
5,287  6,061 
Drilling and completion costs 444,816  312,887 
Other development costs
36,937  8,076 
Change to asset retirement obligations 816  855 
Total exploration and development 513,243  341,280 
Other property and equipment 18,079  46 
Total capital expenditures
$ 531,322  $ 341,326 
Change in accrued capital expenditures and other (13,842) (1,692)
Change in asset retirement obligations (2,026) (855)
Total cash capital expenditures $ 515,454  $ 338,779 
We drilled 61 (30.5 net) wells and completed 61 (30.3 net) Haynesville and Bossier shale wells during the first six months of 2022. We currently expect to spend an additional $440 million to $490 million in the remaining six months of 2022 to drill 42 (28.9 net) additional wells, to complete 33 (27.0 net) wells and for other development activity.
Liquidity and Capital Resources
As of June 30, 2022, we had $1.1 billion of liquidity, comprised of unused borrowing capacity under our bank credit facility and $32.3 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. 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 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 2022 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
22



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.
At June 30, 2022, we had $350.0 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 on April 15, 2022. 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, 2022.
Income Taxes
At June 30, 2022, we had $897.4 million in U.S. federal 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 $117.0 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 $790.9 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, 2022, we had natural gas price swap agreements which hedge approximately 58.9 Bcf of our 2022 natural gas production at an average price of $2.68 per MMBtu. We also had natural gas collars to hedge approximately 196.1 Bcf of our 2022 and 2023 natural gas production with an average floor price of $2.86 per MMBtu and an average ceiling price of $7.81 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 June 30, 2022 would decrease the fair value of our natural gas swaps and collars by approximately $67.3 million. A decrease of 10% in the market price of natural gas on June 30, 2022 would increase the fair value of our natural gas swaps and collars by approximately $66.1 million. The impact of hypothetical
23



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 June 30, 2022, 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%. The fair market value of the 5.875% senior notes due in 2030 and the 6.75% senior notes due in 2029 as of June 30, 2022 was $834.7 million and $1.1 billion, respectively, based on the market price of approximately 86.5% and 89% of the face amount of such debt. At June 30, 2022, we had $350.0 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. 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, 2022, 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, 2022 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, 2022 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
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.
24



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 4, 2022 /s/ M. JAY ALLISON 
M. Jay Allison, Chairman and Chief Executive Officer
(Principal Executive Officer)
Date: August 4, 2022 /s/ ROLAND O. BURNS 
Roland O. Burns, President, Chief Financial Officer and Secretary
(Principal Financial and Accounting Officer)

25
Comstock Resources (NYSE:CRK)
Gráfico Histórico do Ativo
De Ago 2022 até Set 2022 Click aqui para mais gráficos Comstock Resources.
Comstock Resources (NYSE:CRK)
Gráfico Histórico do Ativo
De Set 2021 até Set 2022 Click aqui para mais gráficos Comstock Resources.