0001509991false12/312021Q100015099912021-01-012021-03-31xbrli:shares00015099912021-05-05iso4217:USD00015099912021-03-3100015099912020-12-31iso4217:USDxbrli:shares00015099912020-01-012020-03-310001509991us-gaap:CommonStockMember2020-12-310001509991us-gaap:AdditionalPaidInCapitalMember2020-12-310001509991us-gaap:RetainedEarningsMember2020-12-310001509991us-gaap:TreasuryStockMember2020-12-310001509991us-gaap:AdditionalPaidInCapitalMember2021-01-012021-03-310001509991us-gaap:CommonStockMember2021-01-012021-03-310001509991us-gaap:RetainedEarningsMember2021-01-012021-03-310001509991us-gaap:CommonStockMember2021-03-310001509991us-gaap:AdditionalPaidInCapitalMember2021-03-310001509991us-gaap:RetainedEarningsMember2021-03-310001509991us-gaap:TreasuryStockMember2021-03-310001509991us-gaap:CommonStockMember2019-12-310001509991us-gaap:AdditionalPaidInCapitalMember2019-12-310001509991us-gaap:RetainedEarningsMember2019-12-310001509991us-gaap:TreasuryStockMember2019-12-3100015099912019-12-310001509991us-gaap:AdditionalPaidInCapitalMember2020-01-012020-03-310001509991us-gaap:CommonStockMember2020-01-012020-03-310001509991us-gaap:RetainedEarningsMember2020-01-012020-03-310001509991us-gaap:CommonStockMember2020-03-310001509991us-gaap:AdditionalPaidInCapitalMember2020-03-310001509991us-gaap:RetainedEarningsMember2020-03-310001509991us-gaap:TreasuryStockMember2020-03-3100015099912020-03-31kos:segmentxbrli:pure0001509991kos:TheFacilityMember2021-03-310001509991kos:FacilityInterestOrSeniorNotesPlusTheCorporateRevolverMember2021-01-012021-03-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2019-04-300001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2021-03-310001509991kos:FacilityInterestOrSeniorNotesPlusTheCorporateRevolverMember2021-01-310001509991srt:ScenarioForecastMemberkos:FacilityInterestOrSeniorNotesPlusTheCorporateRevolverMember2021-04-012021-06-300001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMember2021-03-310001509991country:GQ2021-01-012021-03-310001509991country:GQ2020-01-012020-03-310001509991country:GH2021-01-012021-03-310001509991country:GH2020-01-012020-03-310001509991kos:U.S.GulfOfMexicoMember2021-01-012021-03-310001509991kos:U.S.GulfOfMexicoMember2020-01-012020-03-310001509991us-gaap:OilAndGasMember2021-01-012021-03-310001509991us-gaap:OilAndGasMember2020-01-012020-03-310001509991kos:FarmDownAgreementMemberkos:BlocksOffshoreSaoTomeAndPrincipeSurinameNamibiaAndSouthAfricaMember2020-09-300001509991kos:FarmDownAgreementMemberkos:BlocksOffshoreSaoTomeAndPrincipeSurinameAndNamibiaMembersrt:MaximumMember2020-09-300001509991kos:FarmDownAgreementMemberkos:BlocksOffshoreSaoTomeAndPrincipeSurinameAndNamibiaMember2020-10-012020-12-310001509991kos:FarmDownAgreementMemberkos:BlocksOffshoreSaoTomeAndPrincipeSurinameAndNamibiaMember2020-01-012020-12-310001509991kos:FarmDownAgreementMemberkos:BlockSouthAfricaMember2021-03-31kos:well0001509991kos:FarmDownAgreementMemberkos:BlocksOffshoreSaoTomeAndPrincipeSurinameAndNamibiaMember2020-09-30kos:payment0001509991kos:TweneboaEnyenraAndNtommeDiscoveriesMemberkos:GhanaNationalPetroleumCorporationMember2021-01-012021-03-310001509991kos:TweneboaEnyenraAndNtommeDiscoveriesMemberkos:GhanaNationalPetroleumCorporationMember2021-03-310001509991kos:TweneboaEnyenraAndNtommeDiscoveriesMemberkos:GhanaNationalPetroleumCorporationMember2020-12-31kos:agreement0001509991kos:NationalOilCompaniesOfMauritaniaAndSenegalMemberkos:CarryAdvanceAgreementsMember2019-02-012019-02-280001509991kos:NationalOilCompaniesOfMauritaniaAndSenegalMemberkos:CarryAdvanceAgreementsMember2021-03-310001509991kos:NationalOilCompaniesOfMauritaniaAndSenegalMemberkos:CarryAdvanceAgreementsMember2020-12-31kos:projectutr:km0001509991kos:YakaarAndTerangaDiscoveriesMember2019-09-012019-09-300001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2021-03-310001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2020-12-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2021-03-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2020-12-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2021-03-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2020-12-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2020-12-310001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMember2020-12-310001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2020-03-310001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2020-04-300001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2020-10-310001509991kos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMemberkos:DebtInstrumentPeriodOneMember2020-07-012020-07-310001509991kos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMemberkos:DebtInstrumentPeriodTwoMember2020-07-012020-07-310001509991us-gaap:SubsequentEventMemberkos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMember2021-05-100001509991us-gaap:SubsequentEventMemberkos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMember2021-05-012021-05-100001509991us-gaap:SubsequentEventMemberus-gaap:LondonInterbankOfferedRateLIBORMemberkos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMember2021-05-012021-05-100001509991srt:ScenarioForecastMemberkos:TheFacilityMemberus-gaap:RevolvingCreditFacilityMember2021-04-012021-06-300001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2018-08-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2018-08-012018-08-310001509991us-gaap:RevolvingCreditFacilityMemberkos:DebtInstrumentPeriodOneMemberkos:CorporateRevolverMember2020-07-012020-07-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMemberkos:DebtInstrumentPeriodTwoMember2020-07-012020-07-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2019-04-012019-04-300001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7875Due2021Member2019-04-300001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2021-03-012021-03-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Memberus-gaap:DebtInstrumentRedemptionPeriodFourMember2021-03-012021-03-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Memberus-gaap:DebtInstrumentRedemptionPeriodFiveMember2021-03-012021-03-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Memberus-gaap:DebtInstrumentRedemptionPeriodOneMember2021-03-012021-03-310001509991us-gaap:DebtInstrumentRedemptionPeriodTwoMemberus-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2021-03-012021-03-310001509991us-gaap:SeniorNotesMemberus-gaap:DebtInstrumentRedemptionPeriodThreeMemberkos:SeniorNotes7500Due2028Member2021-03-012021-03-310001509991kos:TrafiguraMember2020-06-012020-06-300001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMember2020-09-012020-09-300001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMember2020-09-30utr:MBbls0001509991kos:TermApril2021ToDecember2021Memberkos:SwapsWithSoldPutsMemberkos:DatedBrentMember2021-01-012021-03-31iso4217:USDutr:bbl0001509991kos:TermApril2021ToDecember2021Memberkos:SwapsWithSoldPutsMemberkos:DatedBrentMember2021-03-310001509991kos:NYMEXWTIMemberkos:TermApril2021ToJune2021Memberkos:SwapsWithSoldPutsMember2021-01-012021-03-310001509991kos:NYMEXWTIMemberkos:TermApril2021ToJune2021Memberkos:SwapsWithSoldPutsMember2021-03-310001509991kos:TermApril2021ToDecember2021Memberkos:DatedBrentMemberkos:ThreeWayCollarsMember2021-01-012021-03-310001509991kos:TermApril2021ToDecember2021Memberkos:DatedBrentMemberkos:ThreeWayCollarsMember2021-03-310001509991kos:NYMEXWTIMemberkos:TermApril2021ToDecember2021Memberkos:ThreeWayCollarsMember2021-01-012021-03-310001509991kos:NYMEXWTIMemberkos:TermApril2021ToDecember2021Memberkos:ThreeWayCollarsMember2021-03-310001509991kos:TermApril2021ToDecember2021Memberkos:DatedBrentMemberkos:SoldCallsMember2021-01-012021-03-310001509991kos:TermApril2021ToDecember2021Memberkos:DatedBrentMemberkos:SoldCallsMember2021-03-310001509991kos:TermJanuary2022ToDecember2022Memberkos:DatedBrentMemberkos:ThreeWayCollarsMember2021-01-012021-03-310001509991kos:TermJanuary2022ToDecember2022Memberkos:DatedBrentMemberkos:ThreeWayCollarsMember2021-03-310001509991kos:TermJanuary2022ToDecember2022Memberkos:DatedBrentMemberkos:SoldCallsMember2021-01-012021-03-310001509991kos:TermJanuary2022ToDecember2022Memberkos:DatedBrentMemberkos:SoldCallsMember2021-03-310001509991us-gaap:NondesignatedMemberus-gaap:CommodityContractMember2021-03-310001509991us-gaap:NondesignatedMemberus-gaap:CommodityContractMember2020-12-310001509991kos:ReceivablesOilSalesMemberus-gaap:NondesignatedMemberkos:ProvisionalOilSalesMember2021-03-310001509991kos:ReceivablesOilSalesMemberus-gaap:NondesignatedMemberkos:ProvisionalOilSalesMember2020-12-310001509991us-gaap:NondesignatedMember2021-03-310001509991us-gaap:NondesignatedMember2020-12-310001509991us-gaap:SalesMemberkos:ProvisionalOilSalesMember2021-01-012021-03-310001509991us-gaap:SalesMemberkos:ProvisionalOilSalesMember2020-01-012020-03-310001509991us-gaap:DerivativeMemberus-gaap:CommodityContractMember2021-01-012021-03-310001509991us-gaap:DerivativeMemberus-gaap:CommodityContractMember2020-01-012020-03-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMember2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMemberus-gaap:FairValueInputsLevel2Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMemberus-gaap:FairValueInputsLevel3Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMember2021-03-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMember2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMemberus-gaap:FairValueInputsLevel2Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMemberus-gaap:FairValueInputsLevel3Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMember2021-03-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMember2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2021-03-310001509991us-gaap:FairValueMeasurementsRecurringMember2021-03-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMember2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMemberus-gaap:FairValueInputsLevel2Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMemberus-gaap:FairValueInputsLevel3Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:CommodityContractMember2020-12-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMember2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMemberus-gaap:FairValueInputsLevel2Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMemberus-gaap:FairValueInputsLevel3Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberkos:ProvisionalOilSalesMember2020-12-310001509991us-gaap:FairValueInputsLevel1Memberus-gaap:FairValueMeasurementsRecurringMember2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2020-12-310001509991us-gaap:FairValueMeasurementsRecurringMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberkos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2021-03-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberkos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMember2020-12-310001509991kos:SeniorNotes7.125Due2026Memberus-gaap:SeniorNotesMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2021-03-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Memberus-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Member2020-12-310001509991us-gaap:SeniorNotesMemberkos:SeniorNotes7500Due2028Memberus-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberkos:GoMTermLoanMemberus-gaap:SecuredDebtMember2021-03-310001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberkos:GoMTermLoanMemberus-gaap:SecuredDebtMember2020-12-310001509991kos:GoMTermLoanMemberus-gaap:SecuredDebtMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2021-03-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMember2020-12-310001509991us-gaap:RevolvingCreditFacilityMemberkos:CorporateRevolverMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2021-03-310001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMember2020-12-310001509991us-gaap:RevolvingCreditFacilityMemberkos:TheFacilityMemberus-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMember2021-03-310001509991us-gaap:EstimateOfFairValueFairValueDisclosureMember2021-03-310001509991us-gaap:CarryingReportedAmountFairValueDisclosureMember2020-12-310001509991us-gaap:EstimateOfFairValueFairValueDisclosureMember2020-12-310001509991us-gaap:FairValueMeasurementsNonrecurringMember2020-03-3100015099912020-10-012020-12-3100015099912020-01-012020-12-310001509991kos:LongTermIncentivePlanMember2021-01-012021-03-310001509991kos:LongTermIncentivePlanMember2020-01-012020-03-310001509991kos:ServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2020-12-310001509991kos:MarketAndServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2020-12-310001509991kos:ServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2021-01-012021-03-310001509991kos:MarketAndServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2021-01-012021-03-310001509991kos:ServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2021-03-310001509991kos:MarketAndServiceVestingRestrictedStockUnitsMemberkos:LongTermIncentivePlanMember2021-03-310001509991kos:MarketAndServiceVestingRestrictedStockUnitsMembersrt:MinimumMemberkos:LongTermIncentivePlanMember2021-01-012021-03-310001509991kos:MarketAndServiceVestingRestrictedStockUnitsMembersrt:MaximumMemberkos:LongTermIncentivePlanMember2021-01-012021-03-310001509991kos:LongTermIncentivePlanMemberus-gaap:RestrictedStockUnitsRSUMember2021-03-310001509991kos:LongTermIncentivePlanMemberus-gaap:RestrictedStockUnitsRSUMember2021-01-012021-03-310001509991us-gaap:SubsequentEventMemberkos:LongTermIncentivePlanMember2021-04-012021-04-300001509991kos:LongTermIncentivePlanMember2021-03-310001509991srt:ScenarioForecastMemberkos:LongTermIncentivePlanMember2021-06-300001509991country:US2021-01-012021-03-310001509991country:US2020-01-012020-03-310001509991kos:OtherForeignCountriesMember2021-01-012021-03-310001509991kos:OtherForeignCountriesMember2020-01-012020-03-310001509991kos:GhanaAndEquatorialGuineaMember2021-01-012021-03-310001509991country:MR2021-01-012021-03-31utr:sqkm0001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMemberkos:BureauOfOceanEnergyManagementMember2021-03-310001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMemberkos:BureauOfOceanEnergyManagementMember2020-12-310001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMemberkos:ThirdPartyMember2021-03-310001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMemberkos:ThirdPartyMember2020-12-310001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMember2020-12-310001509991kos:U.S.GulfOfMexicoMemberus-gaap:SuretyBondMember2021-03-3100015099912020-03-262020-03-260001509991us-gaap:OperatingSegmentsMemberkos:GhanaSegmentMember2021-01-012021-03-310001509991us-gaap:OperatingSegmentsMemberkos:EquatorialGuineaSegmentMember2021-01-012021-03-310001509991us-gaap:OperatingSegmentsMemberkos:MauritaniaAndSenegalSegmentMember2021-01-012021-03-310001509991us-gaap:OperatingSegmentsMemberkos:U.S.GulfOfMexicoSegmentMember2021-01-012021-03-310001509991us-gaap:CorporateNonSegmentMember2021-01-012021-03-310001509991us-gaap:IntersegmentEliminationMember2021-01-012021-03-310001509991us-gaap:OperatingSegmentsMemberkos:GhanaSegmentMember2021-03-310001509991us-gaap:OperatingSegmentsMemberkos:EquatorialGuineaSegmentMember2021-03-310001509991us-gaap:OperatingSegmentsMemberkos:MauritaniaAndSenegalSegmentMember2021-03-310001509991us-gaap:OperatingSegmentsMemberkos:U.S.GulfOfMexicoSegmentMember2021-03-310001509991us-gaap:CorporateNonSegmentMember2021-03-310001509991us-gaap:IntersegmentEliminationMember2021-03-310001509991us-gaap:OperatingSegmentsMemberkos:GhanaSegmentMember2020-01-012020-03-310001509991us-gaap:OperatingSegmentsMemberkos:EquatorialGuineaSegmentMember2020-01-012020-03-310001509991us-gaap:OperatingSegmentsMemberkos:MauritaniaAndSenegalSegmentMember2020-01-012020-03-310001509991us-gaap:OperatingSegmentsMemberkos:U.S.GulfOfMexicoSegmentMember2020-01-012020-03-310001509991us-gaap:CorporateNonSegmentMember2020-01-012020-03-310001509991us-gaap:IntersegmentEliminationMember2020-01-012020-03-310001509991us-gaap:OperatingSegmentsMemberkos:GhanaSegmentMember2020-03-310001509991us-gaap:OperatingSegmentsMemberkos:EquatorialGuineaSegmentMember2020-03-310001509991us-gaap:OperatingSegmentsMemberkos:MauritaniaAndSenegalSegmentMember2020-03-310001509991us-gaap:OperatingSegmentsMemberkos:U.S.GulfOfMexicoSegmentMember2020-03-310001509991us-gaap:CorporateNonSegmentMember2020-03-310001509991us-gaap:IntersegmentEliminationMember2020-03-31

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 March 31, 2021
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from               to              
 
Commission file number:  001-35167
 
KOS-20210331_G1.JPG
Kosmos Energy Ltd.
(Exact name of registrant as specified in its charter)
Delaware   98-0686001
(State or other jurisdiction of   (I.R.S. Employer
incorporation or organization)   Identification No.)
8176 Park Lane
Dallas, Texas 75231
(Address of principal executive offices) (Zip Code)
 
Title of each class Trading Symbol Name of each exchange on which registered:
Common Stock $0.01 par value KOS New York Stock Exchange
London Stock Exchange
 
Registrant’s telephone number, including area code: +1 214 445 9600
 
Not applicable
(Former name, former address and former fiscal year, if changed since last report)
 
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   No 
 
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).  Yes   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.
Large accelerated filer   Accelerated filer
     
Non-accelerated filer   Smaller reporting company
(Do not check if a smaller reporting company)    
    Emerging growth 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 
 
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
Class Outstanding at May 5, 2021
Common Shares, $0.01 par value   408,048,315



TABLE OF CONTENTS
 
Unless otherwise stated in this report, references to “Kosmos,” “we,” “us” or “the company” refer to Kosmos Energy Ltd. and its wholly owned subsidiaries. We have provided definitions for some of the industry terms used in this report in the “Glossary and Selected Abbreviations” beginning on page 3.
 
  Page
PART I. FINANCIAL INFORMATION  
   
3
   
7
7
8
9
   
PART II. OTHER INFORMATION  
   
2


KOSMOS ENERGY LTD.
GLOSSARY AND SELECTED ABBREVIATIONS
 
The following are abbreviations and definitions of certain terms that may be used in this report. Unless listed below, all defined terms under Rule 4-10(a) of Regulation S-X shall have their statutorily prescribed meanings.
 
“2D seismic data” Two‑dimensional seismic data, serving as interpretive data that allows a view of a vertical cross‑section beneath a prospective area.
“3D seismic data” Three‑dimensional seismic data, serving as geophysical data that depicts the subsurface strata in three dimensions. 3D seismic data typically provides a more detailed and accurate interpretation of the subsurface strata than 2D seismic data.
"ANP-STP" Agencia Nacional Do Petroleo De Sao Tome E Principe.
“API” A specific gravity scale, expressed in degrees, that denotes the relative density of various petroleum liquids. The scale increases inversely with density. Thus lighter petroleum liquids will have a higher API than heavier ones.
"Asset Coverage Ratio" The "Asset Coverage Ratio" as defined in the GoM Term Loan means, as of each March 31, June 30, September 30 and December 31 of each Fiscal Year, commencing December 31, 2020, the ratio of (a) Total PDP PV-10 (as defined in the GoM Term Loan) as of such date to (b) outstanding principal amount of Loans (as defined in the GoM Term Loan) as of such date.
“ASC” Financial Accounting Standards Board Accounting Standards Codification.
“ASU” Financial Accounting Standards Board Accounting Standards Update.
“Barrel” or “Bbl” A standard measure of volume for petroleum corresponding to approximately 42 gallons at 60 degrees Fahrenheit.
“BBbl” Billion barrels of oil.
“BBoe” Billion barrels of oil equivalent.
“Bcf” Billion cubic feet.
“Boe” Barrels of oil equivalent. Volumes of natural gas converted to barrels of oil using a conversion factor of 6,000 cubic feet of natural gas to one barrel of oil.
"BOEM" Bureau of Ocean Energy Management.
“Boepd” Barrels of oil equivalent per day.
“Bopd” Barrels of oil per day.
"BP" BP p.l.c. and related subsidiaries.
“Bwpd” Barrels of water per day.
"Corporate Revolver" Revolving Credit Facility Agreement dated November 23, 2012 (as amended or as amended and restated from time to time).
"COVID-19" Coronavirus disease 2019.
“Debt cover ratio” The “debt cover ratio” is broadly defined, for each applicable calculation date, as the ratio of (x) total long‑term debt less cash and cash equivalents and restricted cash, to (y) the aggregate EBITDAX (see below) of the Company for the previous twelve months.
“Developed acreage” The number of acres that are allocated or assignable to productive wells or wells capable of production.
“Development” The phase in which an oil or natural gas field is brought into production by drilling development wells and installing appropriate production systems.
"DGE" Deep Gulf Energy (together with its subsidiaries).
"DST" Drill stem test.
“Dry hole” or "Unsuccessful well" A well that has not encountered a hydrocarbon bearing reservoir expected to produce in commercial quantities.
"DT" Deepwater Tano.
3

“EBITDAX” Net income (loss) plus (i) exploration expense, (ii) depletion, depreciation and amortization expense, (iii) equity‑based compensation expense, (iv) unrealized (gain) loss on commodity derivatives (realized losses are deducted and realized gains are added back), (v) (gain) loss on sale of oil and gas properties, (vi) interest (income) expense, (vii) income taxes, (viii) loss on extinguishment of debt, (ix) doubtful accounts expense and (x) similar other material items which management believes affect the comparability of operating results.
"ESG" Environmental, social, and governance.
"ESP" Electric submersible pump.
“E&P” Exploration and production.
"Facility" Facility agreement dated March 28, 2011 (as amended or as amended and restated from time to time).
“FASB” Financial Accounting Standards Board.
“Farm‑in” An agreement whereby a party acquires a portion of the participating interest in a block from the owner of such interest, usually in return for cash and/or for taking on a portion of future costs or other performance by the assignee as a condition of the assignment.
“Farm‑out” An agreement whereby the owner of the participating interest agrees to assign a portion of its participating interest in a block to another party for cash and/or for the assignee taking on a portion of future costs and/or other work as a condition of the assignment.
"FEED" Front End Engineering Design.
“Field life cover ratio”
The “field life cover ratio” is broadly defined, for each applicable forecast period, as the ratio of (x) the forecasted net present value of net cash flow through depletion plus the net present value of the forecast of certain capital expenditures incurred in relation to the Ghana and Equatorial Guinea assets, to (y) the aggregate loan amounts outstanding under the Facility.
"FLNG" Floating liquefied natural gas.
“FPS” Floating production system.
“FPSO” Floating production, storage and offloading vessel.
"GAAP" Generally Accepted Accounting Principles in the United States of America.
"GEPetrol" Guinea Equatorial De Petroleos.
"GHG" Greenhouse gas.
"GJFFDP" Greater Jubilee Full Field Development Plan.
"GNPC" Ghana National Petroleum Corporation.
"GoM Term Loan" Senior Secured Term Loan Credit Agreement dated September 30, 2020.
“Greater Tortue Ahmeyim” Ahmeyim and Guembeul discoveries.
"GTA UUOA" Unitization and Unit Operating Agreement covering the Greater Tortue Ahmeyim Unit.
"HLS" Heavy Louisiana Sweet.
"H&M" Hull and Machinery insurance.
"Jubilee UUOA" Unitization and Unit Operating Agreement covering the Jubilee Unit.
“Interest cover ratio” The “interest cover ratio” is broadly defined, for each applicable calculation date, as the ratio of (x) the aggregate EBITDAX (see above) of the Company for the previous twelve months, to (y) interest expense less interest income for the Company for the previous twelve months.
"LNG" Liquefied natural gas.
“Loan life cover ratio” The “loan life cover ratio” is broadly defined, for each applicable forecast period, as the ratio of (x) net present value of forecasted net cash flow through the final maturity date of the Facility plus the net present value of forecasted capital expenditures incurred in relation to the Ghana and Equatorial Guinea assets, to (y) the aggregate loan amounts outstanding under the Facility.
"LSE" London Stock Exchange.
"LTIP" Long Term Incentive Plan.
“MBbl” Thousand barrels of oil.
4

“MBoe” Thousand barrels of oil equivalent.
“Mcf” Thousand cubic feet of natural gas.
“Mcfpd” Thousand cubic feet per day of natural gas.
“MMBbl” Million barrels of oil.
“MMBoe” Million barrels of oil equivalent.
"MMBtu" Million British thermal units.
“MMcf” Million cubic feet of natural gas.
“MMcfd” Million cubic feet per day of natural gas.
"MMTPA" Million metric tonnes per annum.
“Natural gas liquid” or “NGL” Components of natural gas that are separated from the gas state in the form of liquids. These include propane, butane, and ethane, among others.
"NYSE" New York Stock Exchange.
"Ophir" Ophir Energy plc.
“Petroleum contract” A contract in which the owner of hydrocarbons gives an E&P company temporary and limited rights, including an exclusive option to explore for, develop, and produce hydrocarbons from the lease area.
“Petroleum system” A petroleum system consists of organic material that has been buried at a sufficient depth to allow adequate temperature and pressure to expel hydrocarbons and cause the movement of oil and natural gas from the area in which it was formed to a reservoir rock where it can accumulate.
“Plan of development” or “PoD” A written document outlining the steps to be undertaken to develop a field.
“Productive well” An exploratory or development well found to be capable of producing either oil or natural gas in sufficient quantities to justify completion as an oil or natural gas well.
“Prospect(s)” A potential trap that may contain hydrocarbons and is supported by the necessary amount and quality of geologic and geophysical data to indicate a probability of oil and/or natural gas accumulation ready to be drilled. The five required elements (generation, migration, reservoir, seal and trap) must be present for a prospect to work and if any of these fail neither oil nor natural gas may be present, at least not in commercial volumes.
“Proved reserves” Estimated quantities of crude oil, natural gas and natural gas liquids that geological and engineering data demonstrate with reasonable certainty to be economically recoverable in future years from known reservoirs under existing economic and operating conditions, as well as additional reserves expected to be obtained through confirmed improved recovery techniques, as defined in SEC Regulation S‑X 4‑10(a)(2).
“Proved developed reserves” Those proved reserves that can be expected to be recovered through existing wells and facilities and by existing operating methods.
“Proved undeveloped reserves” Those proved reserves that are expected to be recovered from future wells and facilities, including future improved recovery projects which are anticipated with a high degree of certainty in reservoirs which have previously shown favorable response to improved recovery projects.
"RSC" Ryder Scott Company, L.P.
"SEC" Securities and Exchange Commission.
"7.125% Senior Notes" 7.125% Senior Notes due 2026.
"7.500% Senior Notes 7.500% Senior Notes due 2028.
“Shelf margin” The path created by the change in direction of the shoreline in reaction to the filling of a sedimentary basin.
"Shell" Royal Dutch Shell and related subsidiaries.
“Stratigraphy” The study of the composition, relative ages and distribution of layers of sedimentary rock.
“Stratigraphic trap” A stratigraphic trap is formed from a change in the character of the rock rather than faulting or folding of the rock and oil is held in place by changes in the porosity and permeability of overlying rocks.
“Structural trap” A topographic feature in the earth’s subsurface that forms a high point in the rock strata. This facilitates the accumulation of oil and gas in the strata.
5

“Structural‑stratigraphic trap” A structural‑stratigraphic trap is a combination trap with structural and stratigraphic features.
“Submarine fan” A fan‑shaped deposit of sediments occurring in a deep water setting where sediments have been transported via mass flow, gravity induced, processes from the shallow to deep water. These systems commonly develop at the bottom of sedimentary basins or at the end of large rivers.
"TAG GSA" TEN Associated Gas - Gas Sales Agreement.
"TEN" Tweneboa, Enyenra and Ntomme.
“Three‑way fault trap” A structural trap where at least one of the components of closure is formed by offset of rock layers across a fault.
"Tortue Phase 1 SPA"
Greater Tortue Ahmeyim Agreement for a Long Term Sale and Purchase of LNG.
"Trafigura Trafigura Group PTD, Ltd. and related subsidiaries including Trafigura Trading LLC.
“Trap” A configuration of rocks suitable for containing hydrocarbons and sealed by a relatively impermeable formation through which hydrocarbons will not migrate.
"Trident" Trident Energy.
“Undeveloped acreage” Lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of natural gas and oil regardless of whether such acreage contains discovered resources.
"WCTP" West Cape Three Points.

6



KOSMOS ENERGY LTD.
CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
  March 31, 2021 December 31, 2020
  (Unaudited)  
Assets    
Current assets:    
Cash and cash equivalents $ 95,242  $ 149,027 
Restricted cash 48,660  195 
Receivables:
Joint interest billings, net 25,305  26,002 
Oil sales 51,236  44,491 
Other 15,866  8,320 
Inventories 153,650  128,972 
Prepaid expenses and other 30,268  27,870 
Derivatives —  15,414 
Total current assets 420,227  400,291 
Property and equipment:    
Oil and gas properties, net 3,359,670  3,310,276 
Other property, net 9,778  10,637 
Property and equipment, net 3,369,448  3,320,913 
Other assets:    
Restricted cash 542  542 
Long-term receivables 142,220  117,497 
Deferred financing costs, net of accumulated amortization of $17,951 and $17,296 at March 31, 2021 and December 31, 2020, respectively
3,051  3,706 
Derivatives —  964 
Other 23,598  23,680 
Total assets $ 3,959,086  $ 3,867,593 
Liabilities and stockholders’ equity    
Current liabilities:    
Accounts payable $ 188,704  $ 221,430 
Accrued liabilities 174,147  203,260 
Current maturities of long-term debt 35,000  7,500 
Derivatives 83,293  28,009 
Total current liabilities 481,144  460,199 
Long-term liabilities:    
Long-term debt, net 2,271,112  2,103,931 
Derivatives 10,244  8,069 
Asset retirement obligations 252,208  244,166 
Deferred tax liabilities 551,540  573,619 
Other long-term liabilities 36,053  37,455 
Total long-term liabilities 3,121,157  2,967,240 
Stockholders’ equity:    
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at March 31, 2021 and December 31, 2020
—  — 
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 452,125,539 and 449,718,317 issued at March 31, 2021 and December 31, 2020, respectively
4,521  4,497 
Additional paid-in capital 2,314,595  2,307,220 
Accumulated deficit (1,725,324) (1,634,556)
Treasury stock, at cost, 44,263,269 shares at March 31, 2021 and December 31, 2020, respectively
(237,007) (237,007)
Total stockholders’ equity 356,785  440,154 
Total liabilities and stockholders’ equity $ 3,959,086  $ 3,867,593 
See accompanying notes.
7

KOSMOS ENERGY LTD.
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)
 (Unaudited)
 
  Three Months Ended
  March 31,
  2021 2020
Revenues and other income:    
Oil and gas revenue $ 176,474  $ 177,780 
Gain on sale of assets 26  — 
Other income, net 70 
Total revenues and other income 176,570  177,781 
Costs and expenses:    
Oil and gas production 45,752  61,603 
Facilities insurance modifications, net 671  8,038 
Exploration expenses 8,181  44,605 
General and administrative 22,441  20,911 
Depletion, depreciation and amortization 76,541  93,302 
Impairment of long-lived assets —  150,820 
Interest and other financing costs, net 24,528  27,835 
Derivatives, net 102,461  (136,038)
Other expenses, net 3,468  23,929 
Total costs and expenses 284,043  295,005 
Loss before income taxes (107,473) (117,224)
Income tax expense (benefit) (16,705) 65,543 
Net loss $ (90,768) $ (182,767)
Net loss per share:    
Basic $ (0.22) $ (0.45)
Diluted $ (0.22) $ (0.45)
Weighted average number of shares used to compute net loss per share:
   
Basic 407,365  404,759 
Diluted 407,365  404,759 
Dividends declared per common share
$ —  $ 0.0452 
 
See accompanying notes.
8

KOSMOS ENERGY LTD.
 CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
 (In thousands)
(Unaudited)
 
      Additional      
  Common Shares Paid-in Accumulated Treasury  
  Shares Amount  Capital Deficit Stock Total
2021:
Balance as of December 31, 2020 449,718  $ 4,497  $ 2,307,220  $ (1,634,556) $ (237,007) $ 440,154 
Dividends —  —  90  —  —  90 
Equity-based compensation —  —  8,327  —  —  8,327 
Restricted stock units 2,408  24  (24) —  —  — 
Tax withholdings on restricted stock units —  —  (1,018) —  —  (1,018)
Net loss —  —  —  (90,768) —  (90,768)
Balance as of March 31, 2021 452,126  $ 4,521  $ 2,314,595  $ (1,725,324) $ (237,007) $ 356,785 
2020:
Balance as of December 31, 2019 445,779  $ 4,458  $ 2,297,221  $ (1,222,970) $ (237,007) $ 841,702 
Dividends ($0.0452 per share)
—  —  (18,918) —  —  (18,918)
Equity-based compensation —  —  10,078  —  —  10,078 
Restricted stock units 3,590  36  (36) —  —  — 
Tax withholdings on restricted stock units —  —  (4,947) —  —  (4,947)
Net loss —  —  —  (182,767) —  (182,767)
Balance as of March 31, 2020 449,369  $ 4,494  $ 2,283,398  $ (1,405,737) $ (237,007) $ 645,148 
 
See accompanying notes.
9

KOSMOS ENERGY LTD.
 CONSOLIDATED STATEMENTS OF CASH FLOWS
 (In thousands)
 (Unaudited)
  Three Months Ended March 31,
  2021 2020
Operating activities    
Net loss $ (90,768) $ (182,767)
Adjustments to reconcile net loss to net cash used in operating activities:
Depletion, depreciation and amortization (including deferred financing costs) 79,112  95,585 
Deferred income taxes (22,079) 72,177 
Unsuccessful well costs and leasehold impairments 1,469  19,228 
Impairment of long-lived assets —  150,820 
Change in fair value of derivatives 106,158  (136,322)
Cash settlements on derivatives, net (including $(28.6) million and $12.0 million on commodity hedges during 2021 and 2020)
(32,998) 9,016 
Equity-based compensation 8,281  9,346 
Gain on sale of assets (26) — 
Other (890) 3,974 
Changes in assets and liabilities:
Increase in receivables (13,278) (26,932)
Increase in inventories (25,045) (27,123)
(Increase) decrease in prepaid expenses and other (2,409) 6,344 
Increase (decrease) in accounts payable (32,726) 79,009 
Decrease in accrued liabilities (21,427) (89,318)
Net cash used in operating activities (46,626) (16,963)
Investing activities    
Oil and gas assets (128,448) (83,716)
Other property (354) (1,537)
Proceeds on sale of assets 631  1,713 
Notes receivable from partners (22,416) (23,983)
Net cash used in investing activities (150,587) (107,523)
Financing activities    
Borrowings under long-term debt 100,000  50,000 
Payments on long-term debt (350,000) — 
Net proceeds from issuance of senior notes 444,375  — 
Tax withholdings on restricted stock units (1,018) (4,947)
Dividends (430) (19,156)
Deferred financing costs (1,034) — 
Net cash provided by financing activities 191,893  25,897 
Net decrease in cash, cash equivalents and restricted cash (5,320) (98,589)
Cash, cash equivalents and restricted cash at beginning of period 149,764  229,346 
Cash, cash equivalents and restricted cash at end of period $ 144,444  $ 130,757 
Supplemental cash flow information    
Cash paid for:    
Interest, net of capitalized interest $ 33,587  $ 54,694 
Income taxes, net of refund received $ 12,947  $ 26,874 
 
See accompanying notes.
10


KOSMOS ENERGY LTD.
 
Notes to Consolidated Financial Statements
(Unaudited)
 
1. Organization
 
Kosmos Energy Ltd. was originally incorporated pursuant to the laws of Bermuda in January 2011 to become a holding company for Kosmos Energy Holdings. Kosmos Energy Ltd. changed its jurisdiction of incorporation from Bermuda to the State of Delaware in December 2018 and transferred all of our equity interests in Kosmos Energy Holdings to a new, wholly-owned subsidiary, Kosmos Energy Delaware Holdings, LLC, a Delaware limited liability company. As a holding company, Kosmos Energy Ltd.’s management operations are conducted through a wholly-owned subsidiary, Kosmos Energy, LLC. The terms “Kosmos,” the “Company,” “we,” “us,” “our,” “ours,” and similar terms refer to Kosmos Energy Ltd. and its wholly-owned subsidiaries, unless the context indicates otherwise.

Kosmos is a full-cycle deepwater independent oil and gas exploration and production company focused along the Atlantic Margins. Our key assets include production offshore Ghana, Equatorial Guinea and U.S. Gulf of Mexico, as well as a world-class gas development offshore Mauritania and Senegal. We also maintain a sustainable proven basin exploration program in Equatorial Guinea, Ghana and U.S. Gulf of Mexico. Kosmos is listed on the New York Stock Exchange and London Stock Exchange and is traded under the ticker symbol KOS.
 
Kosmos is engaged in a single line of business, which is the exploration, development, and production of oil and natural gas. Substantially all of our long-lived assets and all of our product sales are related to operations in four geographic areas: Ghana, Equatorial Guinea, Mauritania/Senegal and U.S. Gulf of Mexico.
 
2. Accounting Policies
 
General
 
The interim consolidated financial statements included in this report are unaudited and, in the opinion of management, include all adjustments of a normal recurring nature necessary for a fair presentation of the results for the interim periods. The results of the interim periods shown in this report are not necessarily indicative of the final results to be expected for the full year. The consolidated financial statements were prepared in accordance with the requirements of the SEC for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by GAAP have been condensed or omitted from these interim consolidated financial statements. These consolidated financial statements and the accompanying notes should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2020, included in our annual report on Form 10-K.

Reclassifications
 
Certain prior period amounts have been reclassified to conform with the current presentation. Such reclassifications had no significant impact on our reported net loss, current assets, total assets, current liabilities, total liabilities, stockholders’ equity or cash flows.

Cash, Cash Equivalents and Restricted Cash 
  March 31, 2021 December 31, 2020
  (In thousands)
Cash and cash equivalents $ 95,242  $ 149,027 
Restricted cash - current 48,660  195 
Restricted cash - long-term 542  542 
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows
$ 144,444  $ 149,764 
 
Cash and cash equivalents include demand deposits and funds invested in highly liquid instruments with original maturities of three months or less at the date of purchase. When our net leverage ratio exceeds 2.50x, we are required under the
11

Facility to maintain a restricted cash balance that is sufficient to meet the payment of interest and fees for the next six-month period on the 7.125% Senior Notes and the 7.500% Senior Notes plus the Corporate Revolver or the Facility, whichever is greater. In January 2021, we restricted cash of approximately $28.5 million and expect to restrict cash of an additional $15.0 million in the second quarter of 2021 to meet our requirements. In February 2021, we amended certain terms of the GoM Term Loan agreement, and as a result we restricted cash of $20.0 million which we expect to be released or be used to paydown the GoM Term Loan in the third quarter of 2021.
 
In accordance with certain of our petroleum contracts, we have posted letters of credit related to performance guarantees for our minimum work obligations. Certain of these letters of credit are cash collateralized in accounts held by us and as such are classified as restricted cash. Upon completion of the minimum work obligations and/or entering into the next phase of the respective petroleum contract, the requirement to post the existing letters of credit will be satisfied and the cash collateral will be released. However, additional letters of credit may be required should we choose to move into the next phase of certain of our petroleum contracts.
 
Inventories
 
Inventories consisted of $128.5 million and $127.5 million of materials and supplies and $25.2 million and $1.5 million of hydrocarbons as of March 31, 2021 and December 31, 2020, respectively. The Company’s materials and supplies inventory primarily consists of casing and wellheads and is stated at the lower of cost, using the weighted average cost method, or net realizable value.
 
Hydrocarbon inventory is carried at the lower of cost, using the weighted average cost method, or net realizable value. Hydrocarbon inventory costs include expenditures and other charges incurred in bringing the inventory to its existing condition. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory costs.

Revenue Recognition

Our oil and gas revenues are recognized when hydrocarbons have been sold to a purchaser at a fixed or determinable price, title has transferred and collection is probable. Certain revenues are based on provisional price contracts which contain an embedded derivative that is required to be separated from the host contract for accounting purposes. The host contract is the receivable from oil sales at the spot price on the date of sale. The embedded derivative, which is not designated as a hedge, is marked to market through oil and gas revenue each period until the final settlement occurs, which generally is limited to the month after the sale.
    
    Oil and gas revenue is composed of the following:
Three Months Ended March 31,
  2021 2020
  (In thousands)
Revenues from contract with customer - Equatorial Guinea $ 26,431  $ 24,370 
Revenues from contract with customer - Ghana 59,351  49,672 
Revenues from contract with customers - U.S. Gulf of Mexico 94,389  103,453 
Provisional oil sales contracts (3,697) 285 
Oil and gas revenue $ 176,474  $ 177,780 

12

Concentration of Credit Risk

Our revenue can be materially affected by current economic conditions and the price of oil and natural gas. However, based on the current demand for crude oil and natural gas and the fact that alternative purchasers are available, we believe that the loss of our marketing agents and/or any of the purchasers identified by our marketing agents would not have a long‑term material adverse effect on our financial position or results of operations. The continued economic disruption resulting from the COVID-19 pandemic could materially impact the Company’s business in future periods. Any potential disruption will depend on the duration and intensity of these events, which are highly uncertain and cannot be predicted at this time.

Recent Accounting Standards

In December 2019, the FASB issued ASU 2019-12, “Simplifying the Accounting for Income Taxes”. Our adoption of ASU 2019-12 on January 1, 2021, did not have a material impact on our income tax expense.

3. Acquisitions and Divestitures

During the third quarter of 2020, Kosmos entered into an agreement with Shell to farm down interests in a portfolio of frontier exploration assets for cash consideration of $96.0 million and future contingent consideration of up to $100.0 million. Under the terms of the agreement, Shell acquired Kosmos' participating interest in blocks offshore Sao Tome and Principe, (excluding Block 5 offshore Sao Tome and Principe), Suriname and Namibia, and will acquire our participating interest in South Africa. Kosmos received proceeds totaling $95.0 million during the fourth quarter of 2020 resulting in gain on sale of assets of $92.1 million, with the remaining proceeds of $1.0 million related to Kosmos' participating interest in South Africa expected to be received in 2021 upon customary approval by the government of The Republic of South Africa. The future contingent consideration is payable by Shell upon approval of the relevant operating committee of an appraisal plan for submission to the relevant governmental authority for any of the first four exploration wells it elects to drill in the purchased assets, excluding South Africa. Shell will pay us $50.0 million for each appraisal plan approved by the relevant operating committee to be submitted, subject to an aggregate cap of $100.0 million, or two $50.0 million payments.

4. Joint Interest Billings, Related Party Receivables and Notes Receivables
 
Joint Interest Billings

The Company’s joint interest billings consist of receivables from partners with interests in common oil and gas properties operated by the Company for shared costs. Joint interest billings are classified on the face of the consolidated balance sheets as current and long-term receivables based on when collection is expected to occur.
 
In Ghana, the foreign contractor group funded GNPC’s 5% share of the TEN development costs. The foreign contractor group is being reimbursed for such costs plus interest out of a portion of GNPC’s TEN production revenues. As of March 31, 2021 and December 31, 2020, the current portions of the joint interest billing receivables due from GNPC for the TEN fields development costs were $5.8 million and $5.8 million, respectively, and the long-term portions were $21.9 million and $21.2 million, respectively.

Notes Receivables    

In February 2019, Kosmos and BP signed Carry Advance Agreements with the national oil companies of Mauritania and Senegal obligating us separately to finance the respective national oil company’s share of certain development costs incurred through first gas production for Greater Tortue Ahmeyim Phase 1, currently projected in 2023. Kosmos’ share for the two agreements combined is up to $239.7 million, which is to be repaid with interest through the national oil companies’ share of future revenues. As of March 31, 2021 and December 31, 2020, the balance due from the national oil companies was $120.3 million and $96.3 million, respectively, which is classified as Long-term receivables on our consolidated balance sheets.

13

5. Property and Equipment
 
Property and equipment is stated at cost and consisted of the following:
 
  March 31, 2021 December 31, 2020
  (In thousands)
Oil and gas properties:    
Proved properties $ 5,479,875  $ 5,369,737 
Unproved properties 505,254  495,390 
Total oil and gas properties 5,985,129  5,865,127 
Accumulated depletion (2,625,459) (2,554,851)
Oil and gas properties, net 3,359,670  3,310,276 
Other property 59,952  59,949 
Accumulated depreciation (50,174) (49,312)
Other property, net 9,778  10,637 
Property and equipment, net $ 3,369,448  $ 3,320,913 
 
We recorded depletion expense of $70.6 million and $87.2 million for the three months ended March 31, 2021 and 2020, respectively. During the three months ended March 31, 2021 and 2020, we recorded asset impairments totaling zero and $150.8 million, respectively, in our consolidated statement of operations in connection with fair value assessments for oil and gas proved properties.
 
6. Suspended Well Costs
 
The following table reflects the Company’s capitalized exploratory well costs on drilled wells as of and during the three months ended March 31, 2021.
 
  March 31, 2021
  (In thousands)
Beginning balance  $ 186,289 
Additions to capitalized exploratory well costs pending the determination of proved reserves  11,330 
Reclassification due to determination of proved reserves  — 
Capitalized exploratory well costs charged to expense  — 
Ending balance  $ 197,619 

The following table provides an aging of capitalized exploratory well costs based on the date drilling was completed and the number of projects for which exploratory well costs have been capitalized for more than one year since the completion of drilling:
 
  March 31, 2021 December 31, 2020
  (In thousands, except well counts)
Exploratory well costs capitalized for a period of one year or less $ 8,841  $ — 
Exploratory well costs capitalized for a period of one to two years 29,110  28,692 
Exploratory well costs capitalized for a period of three years or greater 159,668  157,597 
Ending balance $ 197,619  $ 186,289 
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year
14

 
As of March 31, 2021, the projects with exploratory well costs capitalized for more than one year since the completion of drilling are related to the BirAllah discovery (formerly known as the Marsouin discovery) in Block C8 offshore Mauritania, the Yakaar and Teranga discoveries in the Cayar Offshore Profond block offshore Senegal and the Asam discovery in Block S offshore Equatorial Guinea.
 
BirAllah Discovery — In November 2015, we completed the Marsouin-1 exploration well in the northern part of Block C8 offshore Mauritania, which encountered hydrocarbon pay. Following additional evaluation, a decision regarding commerciality is expected to be made. During the fourth quarter of 2019, we completed the nearby Orca-1 exploration well which encountered hydrocarbon pay. Following additional evaluation, a decision regarding commerciality is expected to be made. The BirAllah and Orca discoveries are being analyzed as a joint development.

Yakaar and Teranga Discoveries — In May 2016, we completed the Teranga-1 exploration well in the Cayar Offshore Profond block offshore Senegal, which encountered hydrocarbon pay. In June 2017, we completed the Yakaar-1 exploration well in the Cayar Offshore Profond block offshore Senegal, which encountered hydrocarbon pay. In November 2017, an integrated Yakaar-Teranga appraisal plan was submitted to the government of Senegal. In September 2019, we completed the Yakaar-2 appraisal well which encountered hydrocarbon pay. The Yakaar-2 well was drilled approximately nine kilometers from the Yakaar-1 exploration well. Following additional evaluation, a decision regarding commerciality is expected to be made. The Yakaar and Teranga discoveries are being analyzed as a joint development.

Asam Discovery — In October 2019, we completed the S-5 exploration well offshore Equatorial Guinea, which encountered hydrocarbon pay. In July 2020, an appraisal plan was approved by the government of Equatorial Guinea. The well is located within tieback range of the Ceiba FPSO and work is currently ongoing to integrate all available data into models to establish the scale of the discovered resource. Additionally, engineering is progressing concepts around required subsea infrastructure necessary for a subsea tieback. Once the appraisal plan involving this work is complete, a decision regarding commerciality will be made.

7. Debt
 
  March 31, 2021 December 31, 2020
  (In thousands)
Outstanding debt principal balances:    
Facility $ 1,000,000  $ 1,200,000 
Corporate Revolver 50,000  100,000 
7.125% Senior Notes
650,000  650,000 
7.500% Senior Notes
450,000  — 
GoM Term Loan 200,000  200,000 
Total 2,350,000  2,150,000 
Unamortized deferred financing costs and discounts (43,888) (38,569)
Total debt, net 2,306,112  2,111,431 
Less: Current maturities of long-term debt (35,000) (7,500)
Long-term debt, net $ 2,271,112  $ 2,103,931 
__________________________________

Facility
 
The Facility supports our oil and gas exploration, appraisal and development programs and corporate activities. As of March 31, 2021, borrowings under the Facility totaled $1.0 billion and the undrawn availability under the facility was $320.0 million. In April 2020, following the lenders' annual redetermination, the available borrowing base and Facility size were both reduced from $1.6 billion to approximately $1.5 billion. In October 2020, as a result of the September 2020 redetermination, the available borrowing base was reduced to approximately $1.32 billion. Additionally, the Company agreed to conduct semi-annual redeterminations every March and September, beginning with March 2021. When our net leverage ratio exceeds 2.50x, we are required under the Facility to maintain a restricted cash balance that is sufficient to meet the payment of interest and fees for the next six-month period on the 7.125% Senior Notes and the 7.500% Senior Notes plus the Corporate Revolver or the
15

Facility, whichever is greater. In January 2021, we restricted approximately $28.5 million in cash and expect to restrict an additional $15.0 million in the second quarter of 2021 to meet our requirements.

As a result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, our ability to comply with one of our financial covenants, the debt cover ratio, may be impacted in future periods. Therefore, in July 2020, we proactively worked with our lender group, prior to any inability to comply with the financial covenants thereunder, to amend the debt cover ratio calculation through December 31, 2021. The amendment makes this covenant less restrictive during the stated period up to a maximum of 4.75x and thereafter gradually returns to the originally agreed upon ratio of 3.5x. We were in compliance with the financial covenants as of the most recent assessment date. The Facility contains customary cross default provisions.

In May 2021, in conjunction with the spring borrowing base redetermination, the Company agreed to an amendment and restatement of the Facility. The amendment includes the following material changes: a reduction in the facility size to $1.25 billion (from $1.5 billion), an increase in the interest margin by 0.5% (applicable interest margin for the first three years is now LIBOR + 3.75%) and an extension in the tenor by two years (final maturity date now occurs in March 2027). The amendment also includes a mechanism for two ESG key performance indicators ("KPIs") to impact the interest margin either positively or negatively based upon delivering emissions targets and achieving certain third party ESG ratings. The KPIs are expected to be agreed upon at the September 2021 redetermination. As amended, the Facility has an available borrowing base of $1.24 billion and total commitments of approximately $1.21 billion. As part of the amendment, Kosmos estimates approximately $15 million for loss on extinguishment of debt during the second quarter of 2021.

 Corporate Revolver
 
In August 2018, we amended and restated the Corporate Revolver maintaining the borrowing capacity at $400.0 million, extending the maturity date from November 2018 to May 2022 and lowering the margin to 5%. This results in lower commitment fees on the undrawn portion of the total commitments, which is 30% per annum of the respective margin. The Corporate Revolver is available for general corporate purposes and for oil and gas exploration, appraisal and development programs. As of March 31, 2021, there were $50.0 million in outstanding borrowings under the Corporate Revolver and the undrawn availability was $350.0 million.

As a result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, our ability to comply with one of our financial covenants, the debt cover ratio, may be impacted in future periods. Therefore, in July 2020, we proactively worked with our lender group, prior to any inability to comply with the financial covenants thereunder, to amend the debt cover ratio calculation through December 31, 2021. The amendment makes this covenant less restrictive during the stated period up to a maximum of 4.75x and thereafter gradually returns to the originally agreed upon ratio of 3.5x. We were in compliance with the financial covenants as of the most recent assessment date. The Corporate Revolver contains customary cross default provisions. 

7.125% Senior Notes due 2026

In April 2019, the Company issued $650.0 million of 7.125% Senior Notes and received net proceeds of approximately $640.0 million after deducting fees and other expenses. We used the net proceeds to redeem all of the previously issued 7.875% Senior Secured Notes due 2021, repay a portion of the outstanding indebtedness under the Corporate Revolver and pay fees and expenses related to the redemption, repayment and the issuance of the 7.125% Senior Notes.

The 7.125% Senior Notes mature on April 4, 2026. Interest is payable in arrears each April 4 and October 4, commencing on October 4, 2019. The 7.125% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the Corporate Revolver and the 7.500% Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility) and all borrowings under the GoM Term Loan. The 7.125% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's U.S. Gulf of Mexico assets, and on a subordinated, unsecured basis by certain subsidiaries that guarantee the Facility. We were in compliance with the financial covenants contained in the 7.125% Senior Notes as of March 31, 2021. The 7.125% Senior Notes contain customary cross default provisions.

7.500% Senior Notes due 2028
In March 2021, the Company issued $450.0 million of 7.500% Senior Notes and received net proceeds of approximately 444.4 million after deducting fees. We used the net proceeds to repay outstanding indebtedness under the
16

Corporate Revolver and the Facility, to pay expenses related to the issuance of the 7.500% Senior Notes and for general corporate purposes.
The 7.500% Senior Notes mature on March 1, 2028. Interest is payable in arrears each March 1 and September 1, commencing on September 1, 2021. The 7.500% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the Corporate Revolver and the 7.125% Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility) and all borrowings under the GoM Term Loan. The 7.500% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's U.S. Gulf of Mexico assets, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and, on a subordinated basis, guarantee the Corporate Revolver and the 7.125% Senior Notes.
At any time prior to March 1, 2024, and subject to certain conditions, the Company may, on one or more occasions, redeem up to 40% of the original principal amount of the 7.500% Senior Notes with an amount not to exceed the net cash proceeds of certain equity offerings at a redemption price of 107.500% of the outstanding principal amount of the 7.500% Senior Notes, together with accrued and unpaid interest and premium, if any, to, but excluding, the date of redemption. Additionally, at any time prior to March 1, 2024 the Company may, on any one or more occasions, redeem all or a part of the 7.500% Senior Notes at a redemption price equal to 100%, plus any accrued and unpaid interest, and plus a “make-whole” premium. On or after March 1, 2024, the Company may redeem all or a part of the 7.500% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest:
Year Percentage
On or after March 1, 2024, but before February 28, 2025 103.750  %
On or after March 1, 2025, but before February 28, 2026 101.875  %
On or after March 1, 2026 and thereafter 100.000  %

We may also redeem the 7.500% Senior Notes in whole, but not in part, at any time if changes in tax laws impose certain withholding taxes on amounts payable on the 7.500% Senior Notes at a price equal to the principal amount of the 7.500% Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the 7.500% Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted.

Upon the occurrence of a change of control triggering event as defined under the 7.500% Senior Notes indenture, the Company will be required to make an offer to repurchase the 7.500% Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase.
If we sell assets, under certain circumstances outlined in the 7.500% Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the 7.500% Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the 7.500% Senior Notes, plus accrued and unpaid interest to, but excluding, the repurchase date.
The 7.500% Senior Notes indenture restricts the ability of the Company and its restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of the Company's subsidiaries to make dividends or other payments to the Company, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. Certain of these covenants will be terminated if the 7.500% Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. We were in compliance with the financial covenants contained in the 7.500% Senior Notes as of March 31, 2021. The 7.500% Senior Notes contain customary cross default provisions.
Production Prepayment Agreement

In June 2020, the Company received $50.0 million from Trafigura under a Production Prepayment Agreement of crude oil sales related to a portion of our U.S. Gulf of Mexico production primarily in 2022 and 2023. The Company terminated the Production Prepayment Agreement and the initial prepayment of $50.0 million advanced under the Production Prepayment Agreement by Trafigura in the second quarter of 2020 was extinguished and converted into the GoM Term Loan as of September 30, 2020.

17

GoM Term Loan    

In September 2020, the Company entered into a five-year $200.0 million senior secured term-loan credit agreement secured against the Company's U.S. Gulf of Mexico assets with net proceeds received of $197.7 million after deducting fees and other expenses. The GoM Term Loan also includes an accordion feature providing for incremental commitments of up to $100.0 million subject to certain conditions. The GoM Term Loan bears interest at an effective rate of approximately 6% per annum and matures in 2025, with principal repayments beginning in the fourth quarter of 2021. We were in compliance with the covenants, representations and warranties contained in the GoM Term Loan as of as of March 31, 2021 (the most recent assessment date). The GoM Term Loan contains customary cross default provisions.

Principal Debt Repayments

At March 31, 2021, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: 
  Payments Due by Year
  Total 2021(2) 2022 2023 2024 2025 Thereafter
  (In thousands)
Principal debt repayments(1) $ 2,350,000  $ 27,500  $ 80,000  $ 387,143  $ 458,571  $ 296,786  $ 1,100,000 
__________________________________
(1)Includes the scheduled principal maturities for the $650.0 million aggregate principal amount of the 7.125% Senior Notes, the $450.0 million aggregate principal amount of the 7.500% Senior Notes and borrowings under the Facility, Corporate Revolver and GoM Term Loan. The scheduled maturities of debt related to the Facility as of March 31, 2021 are based on our level of borrowings and our estimated future available borrowing base commitment levels in future periods. Any increases or decreases in the level of borrowings or increases or decreases in the available borrowing base would impact the scheduled maturities of debt during the next five years and thereafter.
(2)Represents payments for the period April 1, 2021 through December 31, 2021.

Interest and other financing costs, net
 
Interest and other financing costs, net incurred during the periods is comprised of the following:
 
  Three Months Ended March 31,
  2021 2020
  (In thousands)
Interest expense $ 31,435  $ 31,766 
Amortization—deferred financing costs 2,571  2,283 
Capitalized interest (8,641) (6,527)
Deferred interest (194) 314 
Interest income (1,825) (1,079)
Other, net 1,182  1,078 
Interest and other financing costs, net $ 24,528  $ 27,835 


8. Derivative Financial Instruments
 
We use financial derivative contracts to manage exposures to commodity price and interest rate fluctuations. We do not hold or issue derivative financial instruments for trading purposes.
 
We manage market and counterparty credit risk in accordance with our policies and guidelines. In accordance with these policies and guidelines, our management determines the appropriate timing and extent of derivative transactions. We have included an estimate of non-performance risk in the fair value measurement of our derivative contracts as required by ASC 820 — Fair Value Measurement.
 
18

Oil Derivative Contracts
 
The following table sets forth the volumes in barrels underlying the Company’s outstanding oil derivative contracts and the weighted average prices per Bbl for those contracts as of March 31, 2021. Volumes and weighted average prices are net of any offsetting derivative contracts entered into.
      Weighted Average Price per Bbl
      Net Deferred        
      Premium        
Payable/ Sold
Term Type of Contract Index MBbl (Receivable) Swap Put Floor Ceiling
2021:
Apr — Dec Swaps with sold puts Dated Brent 4,500  $ —  $ 53.96  $ 42.92  $ —  $ — 
Apr — Jun Swaps with sold puts NYMEX WTI 500  —  47.75  37.50  —  — 
Apr — Dec Three-way collars Dated Brent 2,750  0.37  —  32.95  40.45  52.84 
Apr — Dec Three-way collars NYMEX WTI 750  1.00  —  37.50  45.00  55.00 
Apr — Dec Sold calls(1) Dated Brent 5,250  —  —  —  —  70.09 
2022:
Jan — Dec Three-way collars Dated Brent 1,500  1.05  —  40.00  50.00  70.00 
Jan — Dec Sold calls(1) Dated Brent 1,581  —  —  —  —  60.00 
__________________________________
(1)Represents call option contracts sold to counterparties to enhance other derivative positions
    
The following tables disclose the Company’s derivative instruments as of March 31, 2021 and December 31, 2020, and gain/(loss) from derivatives during the three months ended March 31, 2021 and 2020, respectively:
 
    Estimated Fair Value
    Asset (Liability)
Type of Contract  Balance Sheet Location March 31, 2021 December 31, 2020
    (In thousands)
Derivatives not designated as hedging instruments:      
Derivative assets:      
Commodity Derivatives assets—current $ —  $ 15,414 
Provisional oil sales Receivables: Oil Sales —  (677)
Commodity Derivatives assets—long-term —  964 
Derivative liabilities:  
Commodity Derivatives liabilities—current (83,293) (28,009)
Commodity Derivatives liabilities—long-term (10,244) (8,069)
Total derivatives not designated as hedging instruments   $ (93,537) $ (20,377)

    Amount of Gain/(Loss)
    Three Months Ended
    March 31,
Type of Contract Location of Gain/(Loss) 2021 2020
    (In thousands)
Derivatives not designated as hedging instruments:
     
Provisional oil sales Oil and gas revenue $ (3,697) $ 284 
Commodity Derivatives, net (102,461) 136,038 
Total derivatives not designated as hedging instruments
  $ (106,158) $ 136,322 
19


Offsetting of Derivative Assets and Derivative Liabilities
 
Our derivative instruments which are subject to master netting arrangements with our counterparties only have the right of offset when there is an event of default. As of March 31, 2021 and December 31, 2020, there was not an event of default and, therefore, the associated gross asset or gross liability amounts related to these arrangements are presented on the consolidated balance sheets.

9. Fair Value Measurements
 
In accordance with ASC 820 — Fair Value Measurement, fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. We prioritize the inputs used in measuring fair value into the following fair value hierarchy:
 
Level 1 — quoted prices for identical assets or liabilities in active markets.
Level 2 — quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs derived principally from or corroborated by observable market data by correlation or other means.
Level 3 — unobservable inputs for the asset or liability. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The following tables present the Company’s assets and liabilities that are measured at fair value on a recurring basis as of March 31, 2021 and December 31, 2020, for each fair value hierarchy level: 
  Fair Value Measurements Using:
  Quoted Prices in      
  Active Markets for Significant Other Significant  
  Identical Assets Observable Inputs Unobservable Inputs  
  (Level 1) (Level 2) (Level 3) Total
  (In thousands)
March 31, 2021        
Assets:        
Commodity derivatives $ —  $ —  $ —  $ — 
Provisional oil sales —  —  —  — 
Liabilities:
Commodity derivatives —  (93,537) —  (93,537)
Total $ —  $ (93,537) $ —  $ (93,537)
December 31, 2020
Assets:
Commodity derivatives $ —  $ 16,378  $ —  $ 16,378 
Provisional oil sales —  (677) —  (677)
Liabilities:
Commodity derivatives —  (36,078) —  (36,078)
Total $ —  $ (20,377) $ —  $ (20,377)
 
The book values of cash and cash equivalents and restricted cash approximate fair value based on Level 1 inputs. Joint interest billings, oil sales and other receivables, and accounts payable and accrued liabilities approximate fair value due to the short-term nature of these instruments. Our long-term receivables, after any allowances for credit losses, and other long-term assets approximate fair value. The estimates of fair value of these items are based on Level 2 inputs.
20

 
Commodity Derivatives
 
Our commodity derivatives represent crude oil collars, put options, call options and swaps for notional barrels of oil at fixed Dated Brent, NYMEX WTI, or Argus LLS oil prices. The values attributable to our oil derivatives are based on (i) the contracted notional volumes, (ii) independent active futures price quotes for the respective index, (iii) a credit-adjusted yield curve applicable to each counterparty by reference to the credit default swap (“CDS”) market and (iv) an independently sourced estimate of volatility for the respective index. The volatility estimate was provided by certain independent brokers who are active in buying and selling oil options and was corroborated by market-quoted volatility factors. The deferred premium is included in the fair market value of the commodity derivatives. See Note 8 — Derivative Financial Instruments for additional information regarding the Company’s derivative instruments.
 
Provisional Oil Sales
 
The value attributable to provisional oil sales derivatives is based on (i) the sales volumes and (ii) the difference in the independent active futures price quotes for the respective index over the term of the pricing period designated in the sales contract and the spot price on the lifting date.
 
Debt
 
The following table presents the carrying values and fair values at March 31, 2021 and December 31, 2020:
 
  March 31, 2021 December 31, 2020
  Carrying Value Fair Value Carrying Value Fair Value
  (In thousands)
7.125% Senior Notes
$ 643,778  $ 629,792  $ 643,524  $ 613,412 
7.500% Senior Notes
444,421  425,066  —  — 
GoM Term Loan 200,000  200,000  200,000  200,000 
Corporate Revolver 50,000  50,000  100,000  100,000 
Facility 1,000,000  1,000,000  1,200,000  1,200,000 
Total $ 2,338,199  $ 2,304,858  $ 2,143,524  $ 2,113,412 
 
The carrying values of our 7.125% Senior Notes and 7.500% Senior Notes represent the principal amounts outstanding less unamortized discounts. The fair values of our 7.125% Senior Notes and 7.500% Senior Notes are based on quoted market prices, which results in a Level 1 fair value measurement. The carrying values of the GoM Term Loan, Corporate Revolver and Facility approximate fair value since they are subject to short-term floating interest rates that approximate the rates available to us for those periods.

Nonrecurring Fair Value Measurements - Long-lived assets

Certain long-lived assets are reported at fair value on a non-recurring basis on the Company's consolidated balance sheet. These long-lived assets are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances. Our long-lived assets are reviewed for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

The Company calculates the estimated fair values of its long-lived assets using the income approach described in the ASC 820 — Fair Value Measurements. Significant inputs associated with the calculation of estimated discounted future net cash flows include anticipated future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These are classified as Level 3 fair value assumptions. The Company utilizes an average of third-party industry forecasts of Dated Brent, adjusted for location and quality differentials, to determine our pricing assumptions. In order to evaluate the sensitivity of the assumptions, we analyze sensitivities to prices, production, and risk adjustment factors.

As a result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, we reviewed our long-lived assets for impairment at March 31, 2020, which resulted in impairment charges of $150.8 million, reducing the carrying value of the properties to their estimated fair values of $243.7 million. During the fourth quarter of 2020
21

the Company recorded additional impairment charges totaling approximately $3.2 million resulting in impairment charges totaling $154.0 million for the year ended December 31, 2020. During the first quarter of 2021, the Company did not recognize impairment of proved oil and gas properties as no impairment indicators were identified. If we experience further declines in oil pricing expectations, increases in our estimated future expenditures or a decrease in our estimated production profile, our long-lived assets could be at risk of additional impairment.
 
10. Equity-based Compensation
 
Restricted Stock Units
 
We record equity-based compensation expense equal to the fair value of share-based payments over the vesting periods of the LTIP awards. We recorded compensation expense from awards granted under our LTIP of $8.3 million and $9.3 million during the three months ended March 31, 2021 and 2020, respectively. The total tax benefit was $1.4 million and $2.1 million during the three months ended March 31, 2021 and 2020, respectively. Additionally, we recorded a net tax shortfall (windfall) related to equity-based compensation of $4.8 million and $0.9 million during the three months ended March 31, 2021 and 2020, respectively. The fair value of awards vested was $6.6 million and $25.5 million during the three months ended March 31, 2021 and 2020, respectively. The Company granted restricted stock units with service vesting criteria and a combination of market and service vesting criteria under the LTIP. Substantially all of these grants vest over three years. Upon vesting, restricted stock units become issued and outstanding stock.
 
The following table reflects the outstanding restricted stock units as of March 31, 2021:
 
    Weighted- Market / Service Weighted-
  Service Vesting Average Vesting Average
  Restricted Stock Grant-Date Restricted Stock Grant-Date
  Units Fair Value Units Fair Value
  (In thousands)   (In thousands)  
Outstanding at December 31, 2020 4,840  $ 5.34  7,859  $ 8.11 
Granted(1) 2,489  2.44  6,710  3.91 
Forfeited(1) (21) 6.08  (1,388) 9.12 
Vested (1,803) 5.91  (1,036) 8.41 
Outstanding at March 31, 2021 5,505  3.85  12,145  5.50 
__________________________________
(1)The restricted stock units with a combination of market and service vesting criteria may vest between 0% and 200% of the originally granted units depending upon market performance conditions. Awards vesting over or under target shares of 100% results in additional shares granted or forfeited, respectively, in the period the market vesting criteria is determined.
 
As of March 31, 2021, total equity-based compensation to be recognized on unvested restricted stock units is $46.6 million over a weighted average period of 2.07 years. In April 2021, the board of directors approved an amendment to the LTIP to add 11.0 million shares to the plan. The amendment will be submitted for approval by our stockholders at the Annual Stockholders Meeting in June 2021. The LTIP currently provides for the issuance of 50.5 million shares pursuant to awards under the plan, and would be increased to 61.5 million shares if the amendment to the LTIP is approved by stockholders. At March 31, 2021, the Company had zero shares that remain available for issuance under the LTIP.
 
For restricted stock units with a combination of market and service vesting criteria, the number of common shares to be issued is determined by comparing the Company’s total shareholder return with the total shareholder return of a predetermined group of peer companies over the performance period and can vest in up to 200% of the awards granted. The grant date fair value ranged from $1.06 to $9.52 per award. The Monte Carlo simulation model utilized multiple input variables that determined the probability of satisfying the market condition stipulated in the award grant and calculated the fair value of the award. The expected volatility utilized in the model was estimated using our historical volatility and the historical volatilities of our peer companies and ranged from 50.0% to 52.0%. The risk-free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant and ranged from 0.2% to 2.5%. For the restricted stock units awarded in 2019 and 2020, the Monte Carlo simulation model included estimated quarterly dividend inputs ranging from $0.000 to $0.050.
22

11. Income Taxes

We evaluate our estimated annual effective income tax rate each quarter, based on current and forecasted business results and enacted tax laws, and apply this tax rate to our ordinary income or loss to calculate our estimated tax expense or benefit. The Company excludes zero tax rate and tax-exempt jurisdictions from our evaluation of the estimated annual effective income tax rate. The tax effect of discrete items are recognized in the period in which they occur at the applicable statutory tax rate.

Income (loss) before income taxes is composed of the following:
 
  Three Months Ended March 31,
  2021 2020
  (In thousands)
United States $ (21,842) $ (190,137)
Foreign (85,631) 72,913 
Income (loss) before income taxes $ (107,473) $ (117,224)
 
For the three months ended, March 31, 2021 and 2020, our effective tax rate was 16% and 56%, respectively. For the three months ended March 31, 2021 and 2020, our overall effective tax rates were impacted by:

The difference in our 21% U.S. income tax reporting rate and the 35% statutory tax rates applicable to our Ghanaian and Equatorial Guinean operations,
Jurisdictions that have a 0% statutory rate or where we have incurred losses and have recorded valuation allowances against the corresponding net deferred tax assets, and
Other non-deductible expenses primarily in the U.S.
Additionally, for the three months ended, March 31, 2020, our overall effective tax rate was impacted by:
$30.9 million deferred tax expense related valuation allowances on U.S. deferred tax assets recognized in prior periods, and
$4.9 million tax benefit associated with a 2018 U.S. tax loss carry back, pursuant to the Coronavirus Aid, Relief, and Economic Security ACT (“CARES ACT”), to an earlier tax year with a higher statutory tax rate.

23

12. Net Loss Per Share
 
The following table is a reconciliation between net loss and the amounts used to compute basic and diluted net loss per share and the weighted average shares outstanding used to compute basic and diluted net loss per share:
  Three Months Ended
  March 31,
  2021 2020
(In thousands, except per share data)
Numerator:    
Net loss allocable to common stockholders $ (90,768) $ (182,767)
Denominator:
Weighted average number of shares outstanding:
Basic 407,365  404,759 
Restricted stock awards and units(1) —  — 
Diluted 407,365  404,759 
Net loss per share:
Basic $ (0.22) $ (0.45)
Diluted $ (0.22) $ (0.45)
__________________________________
(1)We excluded outstanding restricted stock units of 13.1 million and 11.0 million for the three months ended March 31, 2021 and 2020, respectively, from the computations of diluted net loss per share because the effect would have been anti-dilutive.

13. Commitments and Contingencies
 
From time to time, we are involved in litigation, regulatory examinations and administrative proceedings primarily arising in the ordinary course of our business in jurisdictions in which we do business. Although the outcome of these matters cannot be predicted with certainty, management believes none of these matters, either individually or in the aggregate, would have a material effect upon the Company’s financial position; however, an unfavorable outcome could have a material adverse effect on our results from operations for a specific interim period or year.
 
We currently have a commitment to drill two exploration wells and acquire approximately 1,000 square kilometers of 3D seismic in Mauritania.

Performance Obligations

As of March 31, 2021 and December 31, 2020, the Company had performance bonds totaling $195.5 million and $195.5 million, respectively, for our supplemental bonding requirements stipulated by the BOEM and $3.5 million and $7.1 million, respectively, to other operators related to costs anticipated for the plugging and abandonment of certain wells and the removal of certain facilities in our U.S. Gulf of Mexico fields. As of March 31, 2021 and December 31, 2020, we had zero cash collateral against these secured performance bonds.

Dividends

On March 26, 2020, the quarterly cash dividend of $0.0452 per common share was paid to stockholders of record as of March 5, 2020. In March 2020, in response to economic conditions, including oil price volatility and the impact of the COVID-19 pandemic, the Board of Directors decided to suspend the dividend.

24

14. Additional Financial Information
 
Accrued Liabilities
 
Accrued liabilities consisted of the following: 
  March 31, 2021 December 31, 2020
  (In thousands)
Accrued liabilities:    
Exploration, development and production $ 68,464  $ 89,162 
Revenue payable 21,191  15,079 
Current asset retirement obligations 7,282  7,255 
General and administrative expenses 11,012  4,988 
Interest 12,671  23,725 
Income taxes 29,701  37,344 
Taxes other than income 2,684  2,815 
Derivatives 15,139  17,475 
Other 6,003  5,417 
  $ 174,147  $ 203,260 

Asset Retirement Obligations
 
The following table summarizes the changes in the Company's asset retirement obligations as of and during the three months ended March 31, 2021:
  March 31, 2021
  (In thousands)
Asset retirement obligations:  
Beginning asset retirement obligations $ 251,421 
Liabilities incurred during period 3,255 
Liabilities settled during period (87)
Revisions in estimated retirement obligations 30 
Accretion expense 4,871 
Ending asset retirement obligations $ 259,490 

Other Expenses, Net
 
Other expenses, net incurred during the period is comprised of the following: 
  Three Months Ended March 31,
  2021 2020
  (In thousands)
Loss on disposal of inventory $ 367  $ 1,467 
Loss on asset retirement obligations liability settlements 29  2,150 
Restructuring charges 819  13,915 
Other, net 2,253  6,397 
Other expenses, net $ 3,468  $ 23,929 
 
The restructuring charges are for employee severance and related benefit costs incurred as part of a corporate reorganization.
 
25

15. Business Segment Information

Kosmos is engaged in a single line of business, which is the exploration, development and production of oil and gas. At March 31, 2021, the Company had operations in four geographic reporting segments: Ghana, Equatorial Guinea, Mauritania/Senegal and the U.S. Gulf of Mexico. To assess performance of the reporting segments, the Chief Operating Decision Maker reviews capital expenditures. Capital expenditures, as defined by the Company, may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with our consolidated financial statements and notes thereto. Financial information for each area is presented below:
Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total
(In thousands)
Three months ended March 31, 2021
Revenues and other income:
Oil and gas revenue $ 54,053  $ 28,032  $ —  $ 94,389  $ —  $ —  $ 176,474 
Gain on sale of assets —  —  —  —  26  —  26 
Other income, net —  —  —  329  137,499  (137,758) 70 
Total revenues and other income 54,053  28,032  —  94,718  137,525  (137,758) 176,570 
Costs and expenses:
Oil and gas production 12,386  11,629  —  21,737  —  —  45,752 
Facilities insurance modifications, net 671  —  —  —  —  —  671 
Exploration expenses 32  1,893  2,174  1,148  2,934  —  8,181 
General and administrative 2,587  1,051  1,973  5,239  45,105  (33,514) 22,441 
Depletion, depreciation and amortization 23,635  9,191  15  43,251  449  —  76,541 
Impairment of long-lived assets —  —  —  —  —  —  — 
Interest and other financing costs, net(1) 11,916  (369) (9,816) 4,566  20,015  (1,784) 24,528 
Derivatives, net —  —  —  —  102,461  —  102,461 
Other expenses, net 71,121  17,069  784  14,489  2,466  (102,461) 3,468 
Total costs and expenses 122,348  40,464  (4,870) 90,430  173,430  (137,759) 284,043 
Loss before income taxes (68,295) (12,432) 4,870  4,288  (35,905) (107,473)
Income tax expense (benefit) (23,868) 2,634  —  —  4,529  —  (16,705)
Net loss $ (44,427) $ (15,066) $ 4,870  $ 4,288  $ (40,434) $ $ (90,768)
Consolidated capital expenditures $ 4,624  $ 11,424  $ 72,752  $ 24,267  $ 3,482  $ —  $ 116,549 
As of March 31, 2021
Property and equipment, net $ 1,275,156  $ 429,494  $ 659,659  $ 983,208  $ 21,931  $ —  $ 3,369,448 
Total assets $ 1,351,071  $ 726,427  $ 981,710  $ 3,246,891  $ 13,825,435  $ (16,172,448) $ 3,959,086 
______________________________________
(1)Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside.

26

Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total
(In thousands)
Three months ended March 31, 2020
Revenues and other income:
Oil and gas revenue $ 49,708  $ 24,619  $ —  $ 103,453  $ —  $ —  $ 177,780 
Other income, net —  —  447  (112,009) 111,562 
Total revenues and other income 49,709  24,619  —  103,900  (112,009) 111,562  177,781 
Costs and expenses:
Oil and gas production 18,042  11,475  —  32,086  —  —  61,603 
Facilities insurance modifications, net 8,038  —  —  —  —  —  8,038 
Exploration expenses 85  2,719  3,474  13,967  24,360  —  44,605 
General and administrative 3,890  1,738  2,109  4,004  31,862  (22,692) 20,911 
Depletion, depreciation and amortization 19,731  8,894  15  63,834  828  —  93,302 
Impairment of long-lived assets —  —  —  150,820  —  —  150,820 
Interest and other financing costs, net(1) 14,831  (369) (6,626) 4,689  17,094  (1,784) 27,835 
Derivatives, net —  —  —  —  (136,038) —  (136,038)
Other expenses, net (116,372) (15,756) 2,793  3,652  13,574  136,038  23,929 
Total costs and expenses (51,755) 8,701  1,765  273,052  (48,320) 111,562  295,005 
Income (loss) before income taxes 101,464  15,918  (1,765) (169,152) (63,689) —  (117,224)
Income tax expense (benefit) 38,221  4,588  —  30,903  (8,169) —  65,543 
Net income (loss) $ 63,243  $ 11,330  $ (1,765) $ (200,055) $ (55,520) $ —  $ (182,767)
Consolidated capital expenditures $ 16,486  $ 6,770  $ 3,121  $ 38,654  $ 19,434  $ —  $ 84,465 
As of March 31, 2020
Property and equipment, net $ 1,484,630  $ 462,472  $ 444,561  $ 1,024,179  $ 27,095  $ —  $ 3,442,937 
Total assets $ 1,724,154  $ 626,511  $ 611,081  $ 3,078,851  $ 12,235,030  $ (14,091,665) $ 4,183,962 
______________________________________
(1)Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside.
Three Months Ended March 31,
2021 2020
(In thousands)
Consolidated capital expenditures:
Consolidated Statements of Cash Flows - Investing activities:
Oil and gas assets $ 128,448  $ 83,716 
Other property 354  1,537 
Adjustments:
Changes in capital accruals (10,409) (23,310)
Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 6,712  25,377 
Capitalized interest (8,641) (6,527)
Other 85  3,672 
Total consolidated capital expenditures $ 116,549  $ 84,465 
______________________________________
(1)Unsuccessful well costs are included in oil and gas assets when incurred.

27


Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
The following discussion and analysis should be read in conjunction with our consolidated financial statements and notes thereto contained herein and our annual financial statements for the year ended December 31, 2020, included in our annual report on Form 10-K along with the section Management’s Discussion and Analysis of financial condition and Results of Operations contained in such annual report. Any terms used but not defined in the following discussion have the same meaning given to them in the annual report. Our discussion and analysis includes forward-looking statements that involve risks and uncertainties and should be read in conjunction with “Risk Factors” under Item 1A of this report and in the annual report, along with “Forward-Looking Information” at the end of this section for information about the risks and uncertainties that could cause our actual results to be materially different than our forward-looking statements.
 
Overview
 
We are a full-cycle deepwater independent oil and gas exploration and production company focused along the Atlantic Margins. Our key assets include production offshore Ghana, Equatorial Guinea and U.S. Gulf of Mexico, as well as a world-class gas development offshore Mauritania and Senegal. We also maintain a sustainable proven basin exploration program in Equatorial Guinea, Ghana and U.S. Gulf of Mexico.

The ongoing COVID-19 pandemic that emerged at the beginning of 2020 has resulted in travel restrictions, including border closures, travel bans, social distancing restrictions and office closures being ordered in the various countries in which we operate, impacting some of our business operations. These ongoing restrictions have had an impact on the supply chain, resulting in the delay of various operational projects. Globally, the impact of COVID-19 has decreased demand for oil, which also resulted in significant declines in oil prices. The Company’s revenues, earnings, cash flows, capital investments, debt capacity and, ultimately, future rate of growth are highly dependent on oil prices.

Recent Developments
    
Corporate

In March 2021, the Company issued $450.0 million of 7.500% Senior Notes due 2028 and received net proceeds of approximately $444.4 million after deducting fees. We used the net proceeds to repay outstanding indebtedness under the Corporate Revolver and the Facility, to pay expenses related to the issuance of the 7.500% Senior Notes and for general corporate purposes.

Ghana
 
During the first quarter of 2021, Ghana production averaged approximately 109,200 Bopd gross (22,400 Bopd net). Jubilee production averaged approximately 70,400 Bopd gross (16,100 Bopd net) with consistent water injection and gas offtake and TEN production averaged approximately 38,800 Bopd gross (6,300 Bopd net). The Ghana Jubilee catenary anchor leg mooring (“CALM”) buoy, which was delayed during 2020, was installed and commissioned in February 2021. In April 2021, the Company re-commenced a multi-year development drilling program, which is expected to include the drilling and completion of two production wells and one water-injection well in Jubilee and drilling and completion of one gas-injection well in TEN during 2021.

U.S. Gulf of Mexico

Production from the U.S. Gulf of Mexico averaged approximately 20,500 Boepd (net) (~81% oil) for the first quarter of 2021. As a result of subsea operational issues, in December 2020 the Kodiak #2 well located in Mississippi Canyon Block 771 was temporarily shut-in. The shut-in was limited to approximately two months, and the well was brought back online in February 2021.

During the first quarter of 2021, the Company completed the Kodiak #3 development well located in Mississippi Canyon Block 727 (29.1% working interest), which was initially drilled in the first half of 2020. The well is a subsea tieback and was brought online through existing infrastructure to the Devils Tower SPAR in April 2021. After the encouraging results from the Tornado-4 water injection well last year, drilling of the Tornado-5 infill well located in the Green Canyon Block 281 (35.0% working interest) is now planned by the operator in the second quarter of 2021 and expected online in the third quarter of 2021.

28

The Winterfell (formerly known as Monarch) exploration prospect was spud in the fourth quarter of 2020, re-commencing our ILX program in the U.S. Gulf of Mexico. Winterfell was designed to test a sub-salt Upper Miocene prospect located in Green Canyon Block 944. In January 2021, we announced the well encountered approximately 26 meters (85 feet) of net oil pay in two intervals. We are working with our partners on an appraisal plan, including the planned drilling of an appraisal well in the third quarter of 2021, and development options for the discovery.

Equatorial Guinea
    
Production in Equatorial Guinea averaged approximately 30,200 Bopd gross (10,200 Bopd net) in the first quarter of 2021. In April 2021, we completed one ESP conversion and expect to complete two more conversions during 2021. The Company expects to commence the Equatorial Guinea drilling program around the end of the second quarter of 2021.

Mauritania and Senegal

During the first quarter of 2021, BP, as the operator of the Cayar block offshore Senegal, provided notice to the Government of Senegal extending the current license phase in order to provide the block owners additional time to evaluate the natural gas market for the natural gas discovery at Yakaar Teranga.

Greater Tortue Ahmeyim Unit

Phase 1 of the Greater Tortue project is approximately 58% complete at March 31, 2021 with first gas for the project expected in the first half of 2023.


29

Results of Operations
 
All of our results, as presented in the table below, represent operations from Jubilee and TEN fields in Ghana, the U.S. Gulf of Mexico and Equatorial Guinea. Certain operating results and statistics for the three months ended March 31, 2021 and 2020 are included in the following tables:
  Three Months Ended March 31,
2021 2020
  (In thousands, except per volume data)
Sales volumes:
Oil (MBbl) 2,941  3,450 
Gas (MMcf) 1,325  1,982 
NGL (MBbl) 127  193 
Total (MBoe) 3,289  3,973 
Total (Boepd) 36,543  43,659 
Revenues:
Oil sales $ 169,150  $ 171,916 
Gas sales 4,540  3,719 
NGL sales 2,784  2,145 
Total revenues $ 176,474  $ 177,780 
Average oil sales price per Bbl $ 57.51  $ 49.83 
Average gas sales price per Mcf 3.43  1.88 
Average NGL sales price per Bbl 21.92  11.11 
Average total sales price per Boe 53.66  44.74 
Costs:
Oil and gas production, excluding workovers $ 42,492  $ 57,417 
Oil and gas production, workovers 3,260  4,186 
Total oil and gas production costs $ 45,752  $ 61,603 
Depletion, depreciation and amortization $ 76,541  $ 93,302 
Average cost per Boe:
Oil and gas production, excluding workovers $ 12.92  $ 14.45 
Oil and gas production, workovers 0.99  1.05 
Total oil and gas production costs 13.91  15.50 
Depletion, depreciation and amortization 23.27  23.48 
Total $ 37.18  $ 38.98 




30

The following table shows the number of wells in the process of being drilled or in active completion stages, and the number of wells suspended or waiting on completion as of March 31, 2021:
 
<
  Actively Drilling or Wells Suspended or
  Completing Waiting on Completion
  Exploration Development Exploration Development
  Gross Net Gross